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GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 '11.-'1111s7- 1. 907.279.1433 OF ALAS"� Fax: 907.276.7542 www.aogcc.alaska.gov March 8, 2017 Mr. David Kumar Production Manager Cook Inlet Energy 601 W. 5th Avenue, Suite 310 .. 4. ,--------^-^ °"'. Anchorage, AK 99501 RE: No-Flow Verification West McArthur River Unit#5 PTD 1980470 scANNED MAR 1 32017, Dear Mr. Kumar: On February 25, 2017 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of West McArthur River Unit#5. 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#5 prior to the test. The well performance was monitored for three hours with unmeasurable gas flow observed 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#5 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. Sicerely, r--7— .N.,.„., ti, •, ,(271- James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors i • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re �1 1 Z �11 I 9g IC � DATE: 2/18/17 P. I. Supervisor FROM: Matt Herrera SUBJECT: No Flow Test Petroleum Inspector WMRU #5 Cook Inlet Energy PTD 1980470 Travelled to West MacArthur River at Trading Bay and met up with Lead Operator Roy Stonecipher and went over the set up for the no-flow test to be performed on WMRU-#5. They had the tubing and IA twinned in to bleed outside to bleed tank. Also, had a Brooks MT3810 Gas meter and calibrated mirror-back 500psi gauge set up inline to a bleed tank. The gas meter was calibrated to read in standard cubic feet per minute. The mirror back gauge calibration date was 6/24/16; the Brooks gas flow meter was , 7/18/16. The Well had been open to bleed approx. 72 hours prior to testing/inspection. Well is equipped with Electric Submersible Pump (ESP). The following table shows test details: Time Pressures Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 9:30 1/0/12 - 0 - 0 Minimal gas 0 Liquids 10:00 0.6/0/12 Reading Only 10:30 1/0/12 0 0 Minimal gas 0 Liquids 11:00 1/0/12 Reading Only 11:30 0.6/0/12 .. Reading Only 12:00 0.6/0/12 Reading Only 12:30 1/0/12 , 0 0 - Minimal gas 0 Liquids 1 Pressures are T/IA/OA Summary: WMRU #5 shows all the characteristics of a well that meets the requirements for a no-flow determination allowing production without a SSSV. Attachments: none SCANNED MM 201 7. 2017-0218_No-FlowWMRU-5_mh.docx Page 1 of 1 STATE OF ALASKA • ALI.OIL AND GAS CONSERVATION COIVIOSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon LJ Plug Perforations LJ Fracture Stimulate II Pull Tubing U Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: RUN ESP Q 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Cook Inlet Energy,LLC Development Q Exploratory ❑ 198-047 3.Address: 601 W.5th Avenue,Suite 310,Anchorage,AK Stratigraphic[II Service ❑ 6.API Number: 99501 50-133-20486 (G C E I V E D 7.Property Designation(Lease Number): 8.Well Name and Number: C ADL 359111 West McArthur River Unit#5 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): JAN 2 0 2017 N/A West McArthur River Oil Pool �� 11.Present Well Condition Summary: (\a/C Total Depth measured 14,450 feet Plugs measured N/A feet true vertical 9835 feet Junk measured N/A feet Effective Depth measured 14450 feet Packer measured 13390 feet true vertical 9835 feet true vertical 9191 feet Casing Length Size MD TVD Burst Collapse Structural - - - Conductor 103 20 103 103 N/A N/A Surface 2204 13 3/8 2204 2151 5020 2260 Intermediate 6638 9 5/8 6638 6870 6870 4750 Production 6468 7 5/8 12858 8870 6890 4790 Liner 1748 51/2 14433 9800 7740 6280 Perforation depth Measured depth 13485-14180 feet SCANNED MAR 0 3201Z True Vertical depth 9247-9664 feet Tubing(size,grade,measured and true vertical depth) 2 7/8" / 2 7/8" 6.5# /6.5# 13434'MD/11965'MD 9216'TVD/8327'TVD Packers and SSSV(type,measured and true vertical depth) No SSSV Baker F-1 Packer 13390'MD 9191'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: ESP Failed -- -- -- -- Subsequent to operation: 297 70 3645 50 50 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development LI Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil U Gas H WDSPL L7 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: -5110-moi Contact Stephen Ratcliff Email sratcliff@glacieroil.com Printed Name Stephen Ratcliff Title Sr.Drilling Engineer Signature S. __—C-71).......--,\.\ Phone 907-433-3808 Date t f co`17 Form 10-404 Revised 5/2015 24 7 RBDMS o-- SAN L 5 2017 Submit Original Only • • RECEIVED GLACIER JAN 2 0 2017 January 19th, 2017 AOGCC Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Report of Sundry Cook Inlet Energy, LLC: West McArthur River Unit#5 Permit to Drill NO: 198-047 API No: 50-133-20486-00-00 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a Sundry Completion Report for Sundry 316-531 for replacing the failed 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, LLC (a Glacier Oil & Gas Corp. wholly owned company) 10-404 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax •RU-05 Current Completion 110 1/19/2017 Version-Final GLACIER Tubing Hanger-2-7/8"EUE Thread-ID-2.441" i ', • ', 20" 133#L-80 103'MD ID-18.00" Buttress 103'TVD 13 3/8" 68#L-80 2,204'MD Al . ID-12.25" Buttress 2,151'TVD TOL©6,390'MD - 9 5/8" 47#L-80 6,638'MD -mil_ ID-8.50" Buttress 5,011'TVD -- 2-7/8"6.5#L80 EUE Tubing-ID-2.441" Leak between 8,278'-8,287'MD I I -----Expandable liner-ID 6.095"f/8,231'-8,340'MD TOC estimated 11,700'MD .1 -'.-x.-` Dual 3/8"Stainless Flat Pack Lines _..--- ESP Assembly Top©11,965'MD/8,327'TVD it 4 I ELECTRIC SUBMERSIBLE PUMP(ESP) ESP#1 Flat Pack Cable Discharge Unit Assembly � Pump Assembly I ll1 i1 Seal Assembly-Upper/Lower Seals Motor/Motor Gauge Unit Centralizer r.. .- Chemical Injection Check Valve -`r '`e Anode iii „_- ----ESP Assembly Bottom©12,163'MD/8,450'TVD TOL @ 12,695'MD • 7 5/8" 29.7#L-80 12,858'MD ID-6.875" STL 8,870'TVD Hemlock Perforations ,1 551'of Total Perforations MD MD TVD TVD r Top Base Top Base 13,485 13,500 9,247 9,257 Top of tubing cut©13,381'MD/9183'TVD 13,506 13,512 9,260 9,264 • w.` 2 7/8"6.5#P-110 EUE Tubing-ID-2.441" 13,512 13,524 9,264 9,271 R;4 5 1/2"Baker F-1 Packer 13,390'MD/9191'TVD 13,524 13,538 9,271 9,280 ;ti with Seal Assembly 13,548 13,554 9,286 9,290 WLEG©13,434'MD/9216'TVD 13,566 13,579 9,297 9,305 - - 13,582 13,592 9,307 9,313 VI MI 13,592 13,619 9,314 9,330 - - 13,624 13,633 9,333 9,339 ■ if 13,642 13,648 9,344 9,348 - 13,648 13,708 9,348 9,384 IN IN 13,718 13,728 9,390 9,402 - 13,728 13,738 9,396 9,402 _ _ 13,766 13,930 9,418 9,513 - II 13,942 14,008 9,520 9,559 -_ __ 14,045 14,090 9,582 9,609 14,090 14,114 9,609 9,6245 1/2" 15.5#L-80 14,443'MD _ c I 14,126 14,180 9,631 9,664 - ID-4.95" HYD 511 9,800'TVD TD 14,450'MD/9835'TVD • • WMRU-05 Daily Operations Summaries PTD: 198-047/API: 50-133-20486-00-00 12/15/2016 ND Tree. NU BOPE. Continue Rig up. 12/16/2016 Continue Rig up. 12/17/2016 Pressure test BOPE—250 psi low/3,000 psi high (annular 2,500 psi)—good. BOPE test witnessed by AOGCC Representative, Matt Herrera. RD BOPE test equipment. Retrieve BPV. Pull hanger and circulate. 12/18/2016 LD tubing hanger and POH with ESP completion. 12/19/2016 Disassemble failed ESP assembly. Make up new ESP assembly and RIH on 2 7/8" 6.5# L80 EUE tubing to 4932'. 12/20/2016 Continue to TIH with ESP BHA on 2 7/8" 6.5# L80 tubing, installing cannon clamps. MU Tubing hanger and land hanger with end of tubing at 12,163' MD. 12/21/2016 RD ESP running equipment. Set BPV and ND BOPE. Rig down. 12/22/2016 Rig Released. END of WMRU-05 Workover Operations (Sundry 316-531) • • ti OF Tit S• I I/j; A THE STATE Alaska Oil and Gas pwitv 0"; tit 0 A T A 1 f iC� Conservation Commission 333 West Seventh Avenue 17,74-11•1*--l* GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Stephen Ratcliff Sr. Drilling Engineer SCANNED �a q Cook Inlet Energy, LLC 2117, 601 West 5th Avenue, Suite 310 Anchorage, AK 99501 Re: West McArthur River Field, West McArthur River Oil Pool, West McArthur River Unit#5 Permit to Drill Number: 198-047 Sundry Number: 316-531 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 r. Foerster Chair Srf DATED this 31 day of October, 2016. RBDMS 6' NOV - 1 2016 • • RECEIVED • STATE OF ALASKA on 14 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION It a'S /0/10 ` APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 2 + Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 Other: Run ESP 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Cook Inlet Energy,LLC t Exploratory ❑ Development ❑� 198-047 ' 3.Address: ❑ 6.API Number: Stratigraphic ❑ Service 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 50-133-20486-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C0416' West McArthur River Unit#5 Will planned perforations require a spacing exception? Yes ❑ No ❑l V 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(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 14450 _ 9835 .. 14317 , 9721 1793 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 103 20 103 103 N/A N/A Surface 2204 13 3/8 2204 2151 5020 2260 Intermediate 6638 9 5/8 6638 6870 6870 4750 Drilling Liner 6468 7 5/8" 12858 8870 6890 4790 production Liner 1748 5 1/2" 14433 9800 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 12202' Packers and SSSV Type: no SSSV Packers and SSSV MD(ft)and TVD(ft): Baker Model Fl I PKR-13,390'MD/9,191'TVD 12.Attachments: Proposal Summary ❑✓ Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch ❑] Exploratory ❑ Stratigraphic ❑ Development❑✓ ' Service El 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 1-Nov-16 OIL El , WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Stephen Ratcliff Contact Email sratcliff(@..glacieroil.com Printed Name Title Stephen Ratcliff Sr.Drilling Engineer Signature Phone Date f 907-433-3808 ti'D'1M (4 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: , �^ / _ - 1) Plug Integrity ❑ BOP Test L1rJ Mechanical Integrity Test 0 Location Clearance ❑ �1 Other: 1- 3 Da r S c, z4,-,„...../..,P I e,..54— �16 (a w #e .11 I>'e ,-4.."._.Y 14 2 S o`, /.4 3 --17....,34-- ,; i-t.. .� 6 D 2)7.I-, Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No 17f Subsequent Form Required:/C--IC 1 liki.h.11 lo RBDMS t v NOV - 1 2016 APPROVED BY Approved by: P9'"'"`"'"'"'''�� COMMISSIONER THE COMMISSION Date:/42...,3/l c. n_ /'1 Submit Form and Form 10-403 R vised 11/2015 'v�4 O ep`,a/p II lid for 12 months from the date of approval. Attac ments in Duplicate • • GLACIER RECEIVED 6 October 14, 2016 Z��' AOGCC Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry: WMRU-05— ESP Conversion Application Cook Inlet Energy: 50-133-20486-00-00 Dear Ms. Foerster, Cook Inlet Energy hereby submits an Application for Sundry Approval for WMRU-05, PTD: 198-047 requesting permission to pull the existing ESP completion to replace the failed ESP. It is also requested that a no flow test will be performed to omit the vent valve, production packer, and sub surface safety valve. , �•- c, _� . 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 •RU-05 Current Completion •10/13/2016 Version-Final T 1 Tubing Hanger-2-7/8"EUE Thread-ID-2.441" j I '!.: 20" 133#L-80 103'MD ID-18.00" Buttress 103'TVD 13 3/8" 68#L-80 2,204'MD i A. ID-12.25" Buttress 2,151'TVD ":i TOL @ 6,390'MD - 9 5/8" 47#L-80 6,638'MD ID-8.50" Buttress 5,011'TVD r ,. "`- ,'2-7/8"6.5#L80 EUE Tubing-ID-2.441" ■ Leak between 8,278'-8,287'MD 'r,-------------- -_ Expandable liner-ID 6.095"88,231'-8,340'MD ■ TOC estimated 11,700'MD I' l-" - ` -__' Dual 3/8"Stainless Flat Pack Lines Sy r'-- ESP Assembly Top @ 12,202'MD/8,475'TVD • I ELECTRIC SUBMERSIBLE PUMP(ESP) ESP#1 Flat Pack Cable Discharge Unit Assembly -'', Pump Assembly Seal Assembly-Upper/Lower Seals - / Motor/Motor Gauge Unit :�"n Centralizer Chemical Injection Check Valve '%. Anode Anode ,, ESP Assembly Bottom @ 12,229'MD/8,491'ND TOL @ 12,695'MD 7 5/8" 29.7#L-80 12,858'MD ID-6.875" STL 8,870'TVD Hemlock Perforations , 551'of Total Perforations MD MD TVD TVD Top Base Top Base 13,485 13,500 9,247 9,257 Top of tubing cut @ 13,381'MD/9183'TVD 13,506 13,512 9,260 9,264 2 7/8"6.5#P-110 EUE Tubing-ID-2.441" 13,512 13,524 9,264 9,271 , 5 1/2"Baker F-1 Packer 13,390'MD/9191'TVD • 13,524 13,538 9,271 9,280 1 1 with Seal Assembly 13,548 13,554 9,286 9,290 i"I -WLEG 0 13,434'MD/9216'TVD i 3,566 i,,579 9,297 9,305 ____L 13,582 13,592 9,307 9,313 = 13,592 13,619 9,314 9,330 = 13,624 13,633 9,333 9,339 = 13,642 13,648 9,3449,348 = 13,648 13,708 9,3489,384 13,718 13,728 9,390 9,402 13,728 13,738 9,396 9,402 ' 13,766 13,930 9,418 9,513 = 13,942 14,008 9,520 9,559 14,045 14,090 9,582 9,609 14,090 14,114 9,609 9,6245 1/2" 15.5#L-80 14,443'MD 14,126 14,180 9,631 9,664 . I ID-4.95" HYD 511 9,800'TVD TD 14,450'MD/9835'TVD • • GLACIER 1. WELL NAME—WMRU-05 Requirements of 20 AAC 25.005(f) Well Summary Current Status: The well is shut-in due to a failed ESP. Scope of Work: • Rig up Rig 37 • Pull ESP completion and tubing. • Replace ESP. • P/U ESP Completion and RIH to+/- 12,230' MD • N/D BOPE & N/U Production Tree • Turn over to production and flow well. General Well Information: Reservoir Pressure/TVD: 0.31 psi/ft 2,820 psi @ 13,336' MD (9,148' TVD)— PT Log (April 25, 2016) MASP: Reservoir Pressure—(Gas Gradient X TVD) (0.31 psi/ft X 8,540'TVD)—(0.1 psi/ft X 8,540') = 2,647 psi —854 psi = 1,793 psi 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: November 1, 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 • • • • 411( GLACIER a 60-day 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. Uon turning the well over to production, the surface safety valve will be tested with in 5 days of completing the well and C .- bringing it back online. CIE Drilling Manager CIE Sr Drilling Engineer CIE Production Manager Conrad Perry T4 AStephen Ratcliff David Kumar (907) 727-7404 (907) 433-3808 (907) 433-3822 cperry@glacieroii.com sratcliff@glacieroil.com dkumar@glacieroil.com 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-05 Well. 3. Lock out safety systems and power oil. 4. Kill well with 8.7 ppg produced water+ KCI. 5. Ensure that well is dead. Rig Workover 6. Mobilize crew, drilling rig, and equipment to West McArthur Facility. 7. Bei Two-Way Check valve in weii. 8. Rig up on WMRU-05 with Rig 37. 9. N/D Production Tree. 10. N/U BOPE. o Notify AOGCC of start of operations and upcoming BOP Test with 48 hours notice. 11. Nipple up and test 13 5/8" BOPE. o Test Rams to 3,000 psi. o Test Annular Bag to j,i5trb psi. a S 6 a 'sem 12. Pull Two Way Check Valve. 3 • • GLACIER 13. Confirm well is dead. 14. Prep equipment, spoolers, and tools to pull ESP Completion. 15. P/U Landing Joint and make up to 2-7/8" Tubing Hanger. 16. Back out Lock Down screws in Tubing Hanger. 17. Pick up while confirming that tubing is free. o Max Pull not to Exceed 110,000 lbs ■ W/O Weight of Blocks 18. Pull & L/D 2-7/8" Landing Joint and Tubing Hanger. 19. Check for Flow and confirm well is dead. 20. POH and L/D the following: o 2-7/8" Tubing o ESP BHA 21. Prep equipment, spoolers, and tools to run ESP Completion. 22. 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 'diner. o Note that the COMPLETION ESP/TUBING WILL NOT BE ROTATED. 23. P/U the following completion equipment as follows: ■ NOTE—Setting Depth of ESP BHA at 12,229' ■ Top of 5-1/2" liner at 12,695' — 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 Park 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 • (1) Stainless steel band at mid point of seal section • (1) Protectolizers ■ Adapter Kit o Pump #1 Assembly—Summit Completions 4 • • • GLACIER • 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 24. RIH to+/- 12,229' o Do not run ESP pump in to 5-1/2" liner at 12,659'. 25. M/U Landing Joint and set completion string in slips. 26. Dress hanger and control lines. 27. Land tubing hanger and test seals to 5,000 psi through test port. 28. Perform final electrical check on cable. 29. L/D Landing Joint. 30. Set Back Pressure Valve. o Observe that well is dead. 31. Complete surface ESP Hookup, Installation, and Tie-In 32. Nipple down BOPE. 33. Nipple up tree and test to 5,000 psi. o Insure that Surface Safety Valve is in place. 34. Confirm with production that well is ready to be brought online and turned over to production. 35. Turn well over to production. 5� 59/ /0.44•!4. 5 • • COOK INLET ENERGY 13-5/8" 5M BOPE ( 13-5/8"SM HYDRIL GK ANNULAR 54-1/8" G U 4,s:,$) `I aim ffnto ). 1 1 13-5/8"5M NOV LXT DBL GATE 31" — DRESSED W/VBR RAMS IN TOP I Ix"z,°, ,x">~)I «} 4.1,/spirPDRESSED W/BLIND RAMS IN BOTTOM ADAPTER SPOOL 19" 13-5/8"5MX11"SM OR 11"10M ^'104" TOTAL STACK HEIGHT ANNULAR STYLE BOP FLUID SPECS: - 17.98 gallon close chamber volume -14.16 gallon open chamber volume LXT BOP FLUID SPECS: -5.14 gallons to close per gate -4.86 gallons to open per gate -6.47:1 closing ratio t TOP VIEW OF VALVES BOLTED TO SIDE OUTLETS OF BOP 7 I 1111111111133. i F 1,-, C I/,,, ,r, ,- II I 13 Pressure(psis) N N N N N N N N N N N N N N IV I i V O V UI L T _ 1 1 f "" I I T I I I I I I I I I I O 1 IV 3 At C it : 1111111 !;! Cn Ij m 2 a iv' N O O _TI N 1 ani V N ID ( w C rsV N inO -4 N V O A N t$ NJO -4 w I I 1 --1-- 8 -- 4:. r. J J -1 1 1 -I•A co N 0) O . OD N 0)) CO CO CO CO Temperature(Deg.F) • • STATE OF ALASKA ALPIPA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS yl 1.Operations Abandon LJ Plug Perforations H Fracture Stimulate LJ Pull Tubing �)A3`Dperations shutdown LJ Performed: Suspend 111 Perforate El Other Stimulate El Alter Casing�AO: iChange Approved Program ❑ Plug for Redrill ❑ erforate New Pool ElRepair Well ❑ Re-enter Susp Well❑ i Other: RUN ESP ❑., 2.Operator Cook Inlet Energy,LLC 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development ❑., Exploratory ❑ 198-047 3.Address: 601 W.5th Avenue,Suite 310,Anchorage,AK Stratigraphic Service ❑ 6.API Number: 99501 50-133-20486-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 359111 West McArthur River Unit#5 y� y 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): '° �"4 N/A West McArthur River Oil Pool t'1 r T 14 2016 ii.Present Well Condition Summary: } (� Total Depth measured 14,450 feet Plugs measured N/A feet')�^'�GC true vertical 9835 feet Junk measured N/A feet Effective Depth measured 14450 feet Packer measured 13390 feet true vertical 9835 feet true vertical 9191 feet Casing Length Size MD TVD Burst Collapse Structural - - - - Conductor 103 20 103 103 N/A N/A Surface 2204 13 3/8 2204 21515020 2260 .m Intermediate 6638 9 5/8 6638 6870 6870 4750 Production 6468 7 5/8 12858 8870 6890 4790 Liner 1748 51/2 14433 9800 7740 6280 Perforation depth Measured depth 13485-14180 feet �i MAR True Vertical depth 9247-9664 feet SCAN�ED 20P, Tubing(size,grade,measured and true vertical depth) 2 7/8" / 2 7/8" 6.5# /6.5# 13434'MD/12202'MD 9216'TVD/8475'TVD Packers and SSSV(type,measured and true vertical depth) No SSSV Baker F-1 Packer 13390'MD 9191'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: 350 80 1850 60 3800 Subsequent to operation: ESP Failed -- -- -- -- 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory El Development Q Service H Stratigraphic H Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas H WDSPL ff Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ H 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: 31(Q— 3 3� Contact Stephen Ratcliff Email sratcliff@glacieroil.com Printed Name Stephen R ff Title Sr. Drilling Engineer Signature 415j? 0�Y/L Phone 907-433-3808 Date � J� Form 10-404 Revised 2015 (_ 7/ _ l ,/'s yl�� / Z � RBDMS ��- OC1 1 9 201 Submit Original Only • • E1VE• GLACIER OCT 14 2016 October 13th, 2016 O Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Report of Sundry Cook Inlet Energy, LLC: West McArthur River Unit#5 Permit to Drill NO: 198-047 API No: 50-133-20486-00-00 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a Sundry Completion Report for Sundry 316-333 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.5th Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax •RU-05 Current Completion •10/13/2016 Version-Final j '':,: Tubing Hanger-2-7/8"EUE Thread-ID-2.441" 20" 133#L-80 103'MD ID-18.00" Buttress 103'TVD 13 3/8" 68#L-80 2,204'MD &. ID-12.25" Buttress 2,151'TVD 'r e l'y TOL @ 6,390'MD ■ 1 9 5/8" 47#L-80 6,638'MD ��2. \ ID-8.50" Buttress 5,011'TVD -2-7/8"6.5#L80 EUE Tubing-ID-2.441" 'kms- --,m _ Leak between 8,278'-8,287'MD ' Expandable liner-ID 6.095"f/8,231'-8,340'MD/ _ie.__ TOC estimated 11,700'MD i� ".. -"' ' Dual 3/8"Stainless Flat Pack Lines 7. t ESP Assembly Top @ 12,202'MD/8,475'TVD 1i r ` ELECTRIC SUBMERSIBLE PUMP(ESP) ESP#1 Flat Pack Cable ' Discharge Unit Assembly II ' Pump Assembly Seal Assembly-Upper/Lower Seals + Motor/Motor Gauge Unit Centralizer Chemical Injection Check Valve j«_ : Anode "'^-ESP Assembly Bottom @ 12,229'MD/8,491'TVD TOL @ 12,695'MD 7 5/8" 29.7#L-80 12,858'MD `- ID-6.875" STL 8,870'TVD Hemlock Perforations d 551'of Total Perforations MD MD TVD TVD , Top Base Top Base 13,485 13,500 9,247 9,257 1 . - Top of tubing cut @ 13,381'MD/9183'TVD 13,506 13,512 9,260 9,264 4 I 2 7/8"6.5#P-110 EUE Tubing-ID-2.441" 13,512 13,524 9,264 9,271 5 1/2"Baker F-1 Packer 13,390'MD/9191'TVD 13,524 13,538 9,271 9,280 1 with Seal Assembly 13,548 13,554 9,286 9,290 - WLEG @ 13,434'MD/9216'TVD 13,566 13,579 9,297 9,305 13,582 13,592 9,307 9,313 13,592 13,619 9,314 9,330 13,624 13,633 9,333 9,339 13,642 13,648 9,344 9,348 13,648 13,708 9,348 9,384 ---- 13,718 13,728 9,390 9,402 13,728 13,738 9,396 9,402 =• 13,766 13,930 9,418 9,513 13,942 14,008 9,520 9,559 , 14,045 14,090 9,582 9,609 14,090 14,114 9,609 9,624 y 5 1/2" 15.5#L-80 14,443'MD 14,126 14,180 9,631 9,664 11 ID-4.95" HYD 511 9,800'TVD TD 14,450'MD/9835'TVD • • WMRU-05 Daily Operations Summaries PTD: 198-047/API: 50-133-20486-00-00 09/04/2016 Rig Move 09/05/2016 Rig Move 09/06/2016 Rig Up 09/07/2016 Rig Up 09/08/2016 Continue Rig up. Rig up to kill well—200 psi on tubing, 30 psi on casing. Bullhead 140 bbls of 8.5ppg produced water. Shut down and monitor pressures. Pump additional 8.5 ppg produced water at 2 bpm. 09/09/2016 Continue circulation at 2 bpm. At 155 bbls pumped, 7.3 ppg crude returns at surface. Pump additional 26 bbls produced water, only 11 bbls returned. Mix and pump 40 bbls, 124 lb/bbl KCL pill. Pump 25 bbls of pill and chase with 52 bbl of 8.5 ppg produced water to EOT. Allow pill to soak. Casing pressure increased to 160psi and fell to 80 psi. Circulate down tubing at 2 bpm, 7.3 ppg returns. Shut in and monitor. Circulate down tubing at 2.2 bpm with no returns until 107 bbls pumped. At 272 bbls pump, 7.3 ppg crude returns at surface. Pump down tubing at 4 bpm, returns to surface at 75 bbls pumped. At 143 bbls pumped, 8.3 ppg produced water at surface. Circulate at 6 bpm with no losses. Total estimated fluid lost to well— 1,324 bbls. Flow check well. 09/10/2016 Attempt to pressure test casing—pressure bleeding off. Set BPV, ND tree. NU BOPE, perform shell test. Pressure test BOPE—250 psi low/3.000 psi high Lannular 2,500 psi)—good. RD BOPE test equipment. Retrieve BPV. RU slickline and RIH —knock out Kobes, fluid equalize, Pull standing valve. 09/11/2016 Continue POH with slickline, RD slickline. Pump and spot 40 bbls salt pill to end of tubing at 3 bpm. No returns while pumping pill. 110 total bbls to fill hole. Work string in attempt to free seals. Pull and set slips. RU E-line and RIH with jet cutter to 13,381' (9' above top of packer). POH with E-line and RD. Pull hanger to floor and LD hanger. Circulate KWF at 6.5 bpm. Flow • S check well. POH and LD 2 7/8"tubing (No abnormal NORM readings, no scale or damage to pipe). Total fluid losses to date = 1,678 bbls. 09/12/2016 Continue POH and LD tubing. LD jet pump cavity/sliding sleeve and cut off joint. MU JS packer and TIH to 6,945' with 2 7/8" 6.5# L80 tubing,tag up and unable to pass. Set packer in 7 5/8" liner at 6,937' MD and test casing to 1500 psi—good. POH with packer and LD. 09/13/2016 RU Slickline and RIH w/5.98" GR to 12,672' without issue, POH. RIH w/6.6" GR to 6,932' WL measurement,jar up with spangs to get free. PU 6 1/8" bit and scraper assy and RIH with 3 %" 12.95# P-110 tubing to 5,960'. 09/14/2016 Continue TIH and tag at 6,939'. Break circulation and rotate, polish 5" with 3-4K torque. CBU at 6 bpm. Continue TIH and tag at 6,960'. Work through to 6,983', 20K overpull to get free. POH and LD scraper assy. RU slickline and RIH with 6.6" GR and tag at 6,970', POH. RIH with 6.25" GR and RIH to 12,672'. MU and RIH with 40 arm caliper to 12,678', logged up to 4,870'. Download data for review. 09/15/2016 Caliper data unreadable. Rerun 40 arm caliper to 12,678' and log up to 5,000' on Slickline. RD Caliper tools. RIH with 3.34" GR to 6,972', unable to pass. RD Slickline. PU and RIH with casing opening tool on 3 %" tubing to open 7 5/8" casing. 09/16/2016 Continue RIH with casing opener to 6,842' and drop ball. Set hanger at 6,975' and work through tight spots from 6,975'to 7,025', 7,649', 7,945', 8,090', 8,410' and 9,080'. RIH from 10,125' to 12,670' and work through tight spot at 10,374'. POH with casing opener to 6,399'. 09/17/2016 Continue POH with casing opener and LD. Rig Up for testing BOPE. Test BOPE to 250 psi low/ 3000psi high (annular to 2 500 psi). Witness waived byAOGCC representative, Jim Re Blind �e gp ) p gg• doors leak repair discussed with AOGCC representative, Lou Grimaldi. 09/18/2016 MU scraper assy and RIH on tubing to 12,690' and tag top of 5 %2" liner. Pump 15 bbl salt pill (hi- vis 9.7 ppg) and circulate out at 7.5 bpm while reciprocating. Flow check and POH to 6,360'. Pump 20 bbls salt pill and circulate out. Continue POH to 1,900'. 09/19/2016 Continue POH and LD scraper assy. MU 7 5/8"JS packer and RIH to 6,971', tag up, unable to pass. POH with JS packer. MU Champ packer and TIH to 7,150'. Set packer and test casing to 1500 psi - good. Continue TIH with Champ packer to 9,225'. • • • 09/20/2016 Continue TIH with Champ packer to 12,665'. Set packer at 12,645',test casing to 1,500 psi—no test. Set packer at 10,330', 8,347', 8,335',test casing to 1,500 psi—no test. Set packer at 7,596', 8,088', 8,271',test casing to 1,500 psi—good test. Set packer at 8,315'—no test. Set packer and perform negative tests at 8,300' and 8,290'. Set packer at 8,280'—good test. Hole in casing estimated between 8,278' and 8,287'. Set packer at 8,315' and attempt to pressure test below casing hole by pumping down tubing—no test. RD test equipment, POH with Champ packer, and LD same. 09/21/2016 Monitor well. Rig maintenance. Waiting for expandable liner to arrive. 09/22/2016 Monitor well. Rig maintenance. MU and RIH with 6 1/8" bit and string mill with 3 1/2"tubing to 8,400'. Flow check. POH and LD BHA. 09/23/2016 Finish LD BHA. RU and test BOPE - 250 psi low/3,000 psi high (annular 2,500 psi)—good. Monitor well and unload expandable liner equipment. MU liner running equipment. V;(2)-- 09/24/2016 MU 3 'A" inner string. MU 6" x 7 5/8" expandable liner. Run inner string in liner and latch into expansion tool. MU Hydraulic setting tool and crossover to tubing. TIH with liner to 8,356'. ' Place bottom of liner at 8,340' and pressure up to function setting tool. Continue pressure build �'. up to 4,300 psi and slowly POH expanding liner.Top of liner at 8,231'. Expandable liner ID of C' 6.095". POH and LD 3 %"tubing to 1,692'. 09/25/2016 Continue LD 3 'A" tubing. LD liner setting tool and inner string. RIH with 3 %" tubing to 4,234'. POH and LD 3 %" tubing. RU to run ESP cable and MU ESP BHA. 09/26/2016 TIH with ESP BHA on 2 7/8" 6.5# L80 tubing, installing cannon clamps,to 5,781'. 09/27/2016 Finish TIH with ESP BHA on 2 7/8"tubing to 12,202' MD. MU Tubing hanger and land hanger with end of tubing at 12,229'. RD ESP running equipment. Set BPV and ND BOPE. 09/28/2016 Continue ND BOPE. Test ESP cable and chemical injection lines—good tests. Rig Released. END of WMRU-05 Workover Operations (Sundry 316-333) • • or 7.4, y*•P��I77 � o THE STATE Alaska Oil and Gas fL1-�® S��:A Conservation Commission __= 1 333 West Seventh Avenue /44T- , GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 �wti ' ` Main: 907.279.1433 ALASFax: 907.276.7542 www.aogcc.alaska.gov Stephen Ratcliff Sr. Drilling Engineer �� Cook Inlet Energy, LLC SEWED 6 601 W. 5th Avenue, Suite 310 • Anchorage, AK 99501 Re: West McArthur River Field, West McArthur River Oil Pool, WMRU 5 Permit to Drill Number: 198-047 Sundry Number: 316-333 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, la;ge_,,, Cathy . Foerster ., Chair DATED this 24ay of June, 2016. RBDMS W JUN L 4 2016 • • STATE OF ALASKA JUN 1 5 2016 • ALASKA OIL AND GAS CONSERVATION COMMISSION 6/23/1,(6, APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 . 1.Type of Request Abandon IJ Plug Perforations 0 Fracture Stimulate IJ Repair Well IJ Operations shutdownu Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 16.3t-i ES P • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Cook Inlet Energy,LLC . Exploratory — Development , ® 198-047 6.API Number: 3.Address. Stratigraphic Service 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 50-133-20486-00-00 N 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO416 • West McArthur River Unit#5 • Will planned perforations require a spacing exception? Yes u No X 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(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): p7 . Plugs(MD): Junk(MD): 14450 9835 14317 9721 /_3474-'; N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 103 20 103 103 N/A N/A Surface 2204 13 3/8 2204 2151 5020 2260 Intermediate 6638 9 5/8 6638 6870 6870 4750 Drilling Liner 6468 7 5/8" 12858 8870 6890 4790 production Liner 1748 5 1/2" 14433 9800 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 13,434 Packers and SSSV Type: no SSSV Packers and SSSV MD(ft)and TVD(ft): Baker Model Fl I PKR-13,390'/9,194' 12.Attachments: Proposal Summary Id Wellbore schematic d I 13.Well Class after proposed work: Detailed Operations Program W BOP Sketch IXI IN Exploratory I I Stratigraphic I I Development IXI. Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 15-Jul-16 OIL ® ' WINJWDSPL Suspended — 16.Verbal Approval: Date: No GAS ❑ WAG GSTOR SPLUG Commission Representative: N/A GINJ1:1 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 Sr.Drilling Engineer :: 6/15/16 Signature Phone Date 12........14) COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test M Mechanical Integ�riitfy Test 111LocationClearance fj Other: 'S Qf)G7 f- S- L)C7 i CAno,._, ,,_ 7f) Post Initial Injection MIT Req'd? Yes ❑ No 2, t, Spacing Exception Required? Yes ❑ No Subsequent Form Required: / 6" G u APPROVED BY 067 Approved by: ....._ COMMISSIONER THE COMMISSION Date. (p --a3- (c c-2/./'' Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approvS1. Attachments in Duplicate ORIGINAL 9Ik `J''//1`° •(1 RBDMS W JUN 1 4 2016 •. < • GLACIER RECEIVED JUN 15 2016 June 15, 2016 ^ AOGCC Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry: WMRU-05 — ESP Conversion Application Cook Inlet Energy: 50-133-20486-00-00 Dear Ms. Foerster, Cook Inlet Energy hereby submits a sundry for WMRU-05, PTD: 198-047 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 • i • < GLACIER 1. WELL NAME—WMRU-05 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 +/- 12,300' MD • N/D BOPE & N/U Production Tree • Turn over to production and flow well General Well Information: Reservoir Pressure/TVD: 0.31 psi/ft 2,820 psi @ 13,336' MD (9,148' TVD)—PT Log (April 25, 2016) MASP: Reservoir Pressure— (Gas Gradient X TVD) (0.31 psi/ft X 8,540' TVD) —(0.1 psi/ft X 8,540') = 2,647 psi —854 psi = 1,793 psi 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 15, 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 a 60-day period to insure against any potential for infancy fai -s 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 -Cif 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-05 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-05 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 to is*psi 15. Pull Two Way Check Valve 16. Confirm well is dead re r:4)6"- 17. R/U E-Line and Lubricator 18. RIH on E-Line to make Tubing Cut above packer with Jet Cutter o Correlate on Depth o Note— Permanent Packer at 13,390' 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 L/D 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 12,600' 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 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+/- 12,300' 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 12,300' ■ Top of 5-1/2" liner at 12,695' — 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 • < S 410 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 +/- 12,300' o Do not run ESP pump in to 5-1/2" liner at 12,659' 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 6 A a f`h — F(c (e t- 4. : 444-' Z, Cl r- WMRU-5 Current Completion 5/2/16 Version-Final j • L 1. 20" L-80 103'MD 1330 Buttress 103'TVD 13 3/8" L-80 2204'MD 68# Buttress 2151'TVD - TOL 6,390' 9 5/8" L-80 6638'MD ' p £ 47# Buttress 5011'TVD ',Ta Xn� l,'i } 4 TOL 12,695' 7 5/8" L-80 12,858'MD 29.7# STL 8870'ND 2 7/8"6.5#P-110 EUE Tubing-ID-2.441" Hemlock Perforations Opti Sliding Sleeve-OD 3.2"-ID-2.313" 462'(existing)+89'(new)=551'of Total Perforations Weatherford Jet Pump-OD-3.55"©13,352' MD MD TVD TVD Jet Pump Cavity-OD-3.55"-ID-2.25" Top Base Top Base , 13,485 13,500 9,247 9,257 .2, Ill f''r' 5 1/2"Baker F-1 Packer 13,390' 13,506 13,512 9,260 9,264 - with Seal Assembly 13,524 13,538 9,271 9,280 13,566 13,579 9,297 9,305 - rJ 13,592 13,619 9,314 9,330 ' 4 13,624 13,633 9,333 9,339 13,648 13,708 9,348 9,384 ' -WLEG @ 13,434 13,728 13,738 9,396 9,402 13,766 13,930 9,418 9,513 0. 13,942 14,0089,520 9,559 -- 14,090 14,114 9,609 9,624 -__ 14,126 14,180 9,631 9,664 89'(new)=551'of Total Perforations • .. 13,512 13,524 9,264 9,271 - 13,548 13,554 9,286 9,290 ., 13,582 13,592 9,307 9,313 ' 13,642 13,648 9,344 9,348 13,718 13,728 9,390 9,402 `. 14,045 14,090 _ 9,582 9,609 ` 5 1/2"15.5#L-80 Hyd 511 14443'MD I 9800'TVD "a L TD 14,450'MD/9835'ND • • WMRU-05 Proposed ESP Completion 5/24/16 Version-1.0 1 -, Tubing Hanger-2-7/8"EUE Thread-ID-2.441" b, - y 20" 133#L-80 103'MD ] ,, . ID-18.00" Buttress 103'TVD rra • I� 13 3/8" 68#L-80 2,204'MD +r el ID-12.25" Buttress 2,151'TVD .t 2-7/8"6.58 L80 EUE Tubing-ID-2.441" TOL @ 6,390'MD 9 518" 47#L-80 6,638'MD 2- ID-8.50" Buttress 5,011'ND P." Li • S COOK INLET ENERGY 13-5/8" 5M BOPE ( 13-5/8" 5M HYDRIL GK ANNULAR 54-1/8" I(°/:' Il 13-5/8" 5M NOV LXT DBL GATE 31" O J DRESSED W/VBR RAMS IN TOP _�' �^.! mi DRESSED W/BLIND RAMS IN BOTTOM =C��z)= -C�vz)=1 +, ,, ti„ 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 71-1 II I J 0 ca 0 0 I J MCV MGV II� II= (d•6ea) ean;eiedwei (O N CO V 0 CO N CO V O (0 N 00 .1- a) O) O) 00 00 00 N- N- CO CO CD LU � V O O ci CO I,- e... r a- O N N_ 4' LU O r N N- 0 in N r-- ,-- 0 0 cs 2 in — N a) a) LL O O N 2 N 7 1.2 a) CL E /\ ) Lo L I •• .c L N ...i aaim d 2 -0 11 . 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V d Ca (eisd) eanssead cc STATE OF ALASKA *KA OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon _ Plug Perforations Fracture Stimulate _ Pull Tubing _ Operations shutdown _ Performed: Suspend _ Perforate X Other Stimulate _ Alter Casing _ Change Approved Program _ Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well_ Other: 2.Operator Cook Inlet Energy,LLC 4.Well Class Before Work: _5.Permit to Drill Number: Name: Development Exploratory _198-047 3.Address: 601 W.5th Avenue,Suite 310,Anchorage,AK Stratigraphic Service PI Number: 99501 0-133-20486-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 359111 West McArthur River Unit#5 iC` " "' 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): iyl/i I ti 2010 N/A West McArthur River Oil Pool 11.Present Well Condition Summary: ® +U cc Total Depth measured 14,450' feet Plugs measured N/A feet true vertical 9,835' feet Junk measured N/A feet Effective Depth measured 14,450' feet Packer measured 13,390' feet true vertical 9,835' feet true vertical 9,194' feet Casing Length Size MD TVD Burst Collapse Structural - - - - - - Conductor 103 20 103 103 N/A N/A Surface 2204 13 3/8 2204 2151 5020 2260 Intermediate 6638 9 5/8 6638 6870 6870 4750 Production 6468 - 7 5/8 12858 8870 6890 4790 Liner 1748 51/2 14433 9800 7740 6280 Perforation depth Measured depth 13,485'-14,180' feet SCANNED JUN 2 7 /.:016 True Vertical depth 9,247'-9,664' feet Tubing(size,grade,measured and true vertical depth) 2 7/8" L-80 13,434' 9,217' Packers and SSSV(type,measured and true vertical depth) No SSSV Baker F-1 Packer 13,390' 9,191' 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 413 103 1744 45 3500 Subsequent to operation: 420 100 1750 48 3500 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations N/A Exploratory n Development® Service Stratigraphic Copies of Logs and Surveys Run N/A 16.Well Status after work: Oil Gas WDSPL Printed and Electronic Fracture Stimulation Data N/A GSTOR [1 VVI NJ n 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: 3I(o-Z3I Contact Stephen Ratcliff Email sratcliff@glacieroil.com Printed Name Stephen Ratcliff `^. , Title Sr.Drilling Engineer . ----' 0..---- Signature v w-- `—CD--\\ Phone 907.433.3808 Date 5/2/16 5--1—/ 6 Form 10-404 Revised 5/2015 /f 6 --(f0 Submit Original Only RBDMS �� MAY c 3 2016 • • _ Cook Inlet Energy_ May2, 2016 RECEIVED MAY 0 2 2016 Ms. Cathy Foerster, Chair A000C Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage,Alaska 99501 Re: WMRU-05 Well Completion Cook Inlet Energy, LLC: Well Name: WMRU-05 Permit to Drill No: 198-047 Sundry No: 316-231 API No: 50-133-20486-00-00 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a Sundry Completion for the added perforations on the WMRU-05 well,located in the West McArthur River Unit. Enclosed please find: 1. Well Completion Report (AOGCC Form 10-404) 2. Completion Schematic If you have any questions, please contact me at (907) 433-3808. Sincerely, \\ Stephen Ratcliff Sr. Drilling Engineer- Cook Inlet Energy 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax 4111/VVMRU-5 Current Completion • 512/16 • Version-Final i ,„. 20" L-80 103'MD 133# Buttress 103'ND ' 1334/8" L-80 2204'MD ilk L 68# Buttress 2151'TVD TOL 6,390' 9 5/8" L 80 6638'MD 47# Buttress 5011'TVD TOL @ 12,695' 7 5/8" L-80 12,858'MD 29.7# STL 8870'ND . • 2 7/8"6.5#P-110 EUE Tubing-ID-2.441" Hemlock Perforations Opti Sliding Sleeve-OD 3.2"-ID-2.313" 462'(existing)+89'(new)=551'of Total Perforations i Weatherford Jet Pump-OD-3.55"@ 13,352' MD MD TVD TVD Jet Pump Cavity-OD-3.55"-ID-2.25" Top Base Top Base 13,485 13,500 9,247 9,257 5 1/2"Baker F-1 Packer 13,390' 13,506 13,512 9,260 9,264 • with Seal Assembly 13,524 13,538 9,271 9,280 , 13,566 13,579 9,297 9,305 13,592 13,619 9,314 9,330 13,624 13,633 9,333 9,339 13,648 13,708 9,348 9,384 WLEG @ 13,434 13,728 13,738 9,396 9,402 13,766 13,930 9,418 9,513 '. v 13,942 14,008 9,520 9,559 14,090 14,114 9,609 9,624 14,126 14,180 9,631 9,664 89'(new)=551'of Total Perforations 13,512 13,524 9,264 9,271 13,548 13,554 9,286 9,290 -.,a, 13,582 13,592 9,307 9,313 13,642 13,648 _ 9,344 9,348 13,718 13,728 _ 9,390 9,402 14,045 14,090 9,582 9,609 5 1/2"15.5#L-80 Hyd 511 14443'MD I 9800'ND TD 14,450'MD/9835'TVD • • Cook Inlet Energy_ WMRU-05 - Perforation Additions - Daily Summaries 4/20/16 R/U Pollard wireline. Test lubricator and prep to pull jet pump. RIH and pull jet pump at 13,310'. RIH w/ equalizer prong and strike Kobe knock outs. 4/21/16 Strike Kobe knockouts. Well on vacuum. POH and L/D tools. RIH with retrieving tool to standing valve. POH with standing valve. RIH with 2.15" Gauge Ring to 13,338'. Tolls stuck in jet pump cvity. Drop cutter bar and free wire. POH with wire and pick up fishing string. RIH to tools and latch fish. POH. 4/22/16 RIH with GR to 14,108'. POH and P/U braded brush. RIH with brush to 13,600'. POH and R/D slickline. 4/23/16- 4/24/16 R/U and prep for perf runs. Test luybricator to 3,500 psi. P/U logging and perf BHA. RIH to 14,061' and fire the following intervals: 13,512 13,524 9,264 9,271 13,548 13,554 9,286 9,290 13,582 13,592 9,307 9,313 13,642 13,648 9,344 9,348 13,718 13,728 9,390 9,402 14,045 14,090 9,582 9,609 R/D Pollard E-Line and prep to run pressure temperature gauges and standing valve. 4/25/16 R/U slickline. RIH with gauges on standing valve. Set in BHA and POH. R/U to pressure test annulus. Pressure test annulus to 1,522 psi, unable to hold with out bleeding off. Attempt 2 more tests with out success. Open valves and bleed off pressure to production. RIH with kobe knock out punch. Let well equalize overnight through standing valve. 601 W.5`h Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax • • 4/26/16 RIH and pull standing valve. POH and inspect standing valve. RIH and close sliding sleeve. POH and prep to pressure test annulus. Pressure test to 800 psi with out success. POH and RIH with shifting tool. Shift sleeve and confirm sleeve is closed. POH with shifting tool. RIH with standing valve and seat below sliding sleeve. POH and pressure test tubing to 3,500 psi. Good test and no communication to annulus. Pressure test annulus to to 1,500 psi. Bled down to 1,100 psi in 10 minutes. Suspect leak at liner lap. Suspend well for night. 1.0 f cv l2c�1c 4/27/16 /4. Prep for low pressure annulus test. Pressure up annulus to 510 psi. Pressure bled off to 300 psi. Monitor annulus pressure at 300 psi for 7 hours. Pressure fell from 300 psi to 296 psi. R/D chart recorder and talk with AOGCC about results. Verbal granted by Guy Schwartz to •-� return well to production until rig can be moved on to well to test annulus. R/D equipment and turn well over to production. 21Pap : • • • SOF T� . y4,\��\�//j,'6, THE STATE Alaska Oil and Gas ti N Of/� LAc1CrT /H� Conservation Commission • S 4 '� 333 West Seventh Avenue ..'tet .- 4.7t,-1•7- GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 0Main: 907.279.1433 Up,ALAS'' Fax: 907.276.7542 www.aogcc.alaska.gov Conrad Perry Drilling Manager Cook Inlet Energy, LLC 601 A 5th Avenue, Suite 310 SCANNED ' r r ,44- Anchorage, AK 99501 Re: West McArthur River Field, West McArthur River Oil Pool, WMRU 5 Permit to Drill Number: 198-047 Sundry Number: 316-231 Dear Mr. Perry: 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, a2 ,0°, .€4,,/,,„_ Cathy P Foerster Chair DATED this `.5 day of April, 2016. RBDMS 1.- APR 1 8 2016 = ECEIVO fi • STATE OF ALASKA 0 APR 11 20 ALASKA OIL AND GAS CONSERVATION COMMISSION 4 i5 . 1--. / 1-3-'1/g- . APPLICATION FOR SUNDRY APPROVALS n �, 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate Q Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Cook Inlet Energy,LLC Exploratory ❑ Development Q 198-047 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 50-133-20486-00-00 7.If perforating: ij(b 8.Well Name and Number: Pj�hj What Regulation or Conservation Order governs well spacing in this pool? 60 i l/b CO¢(9 West Ma /� hur River Unit#5 Will planned perforations require a spacing exception? Yes ❑ No El inC.AA.Tl+tat. 9.Property Designation(Lease-lumber): 10.Field/Pool(s): ADL 359111 r 1' West McArthur River Oil Pool 11. j PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 14450 9835 14317 9721 3171 NA N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 103 20 103 103 N/A N/A Surface 2204 13 3/8 2204 2151 5020 2260 Intermediate 6638 9 5/8 6638 6870 6870 4750 Drilling Liner 6468 7 5/8" 12858 8870 6890 4790 production Liner 1748 5 1/2" 14433 9800 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 13,434 Packers and SSSV Type: no SSSV Packers and SSSV MD(ft)and TVD(ft): Baker Model Fl PKR 13,390'/9194 12.Attachments: Proposal Summary (J Wellbore schematic U 13.Well Class after proposed work: Detailed Operations Program ❑Q BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q Service ❑ 14.Estimated Date for ASAP 15.Well Status after proposed work: Commencing Operations: OIL ❑✓ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved Conrad Perry herein will not be deviated from without prior written approval. Contact Email conrad.perry(a�cookinlet.net Printed Name Conrad per 7-727- 404 Title Drilling Manager 4-3-16 Signature e Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 311(0 --(:). 1, Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: / X / 't �� -(� r ` •_ '.) f 2' /SO p�'- Post Post Initial Injection MIT Req'd? Yes ❑ No ❑ RgpMS L L APR 1 8 2016 Spacing Exception Required? Yes ❑ No j` Subsequent Form Required: I(1 - ,-./ t.,c1 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: e/..._/5--",6 tFor Submit Form and Form 10-403 Re ised 11/2015 Approved aPPlicationU v rGh f Le date of approval. Attachments in Duplicatelicate y_I 2--/G %/(6- • RECEIVED APR 1 1 2016 April 11, 2016 AOGCC Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage,Alaska 99501 RE: Sundry Application WMRU-5 Cook Inlet Energy: 50-133-20486-00-00 Dear Ms. Foerster, Cook Inlet Energy hereby submits a sundry for WMRU-5, PTD: 198-047 requesting permission to add perforations to increase production. If you have any questions, please contact me at 907.727.7404. Sincerely, Conrad 'erry SVP-Drilling Cook Inlet Energy,LLC 601 W.5th Avenue STE 310 Anchorage,AK 99501 1 • • 1. WELL NAME - West MacArthur River Unit #5 Requirements of 20 AAC 25.005(f) Well Summary Current Status: The well is producing. Current Perforations Existing Perfs.4/11/2016 MD TVD Top Base Top Base 13,485 13,500 9247.02 9256.61 13,506 13,512 9260.02 9263.74 13,524 13,538 9271.19 9279.89 13,566 13,579 9297.35 9305.48 13,592 13,619 9313.57 9330.29 13,624 13,633 9333.38 9338.91 13,648 13,708 9348.11 9384.39 13,728 13,738 9396.22 9402.09 13,766 13,930 9418.33 9512.83 13,942 14,008 9519.92 9559.44 14,090 14,114 9609.41 9624.07 14,126 14,180 9631.40 9664.38 NEW Perforations Measured Depth Total Vertical Depth Top I Base Top Base M©Feet Toal 13,512 13,524 9,264 9,271 12 13,548 13,554 9,286 9,290 6 13,582 13,592 9,307 9,313 10 13,642 13,648 9,344 9,348 6 13,718 13,728 " 9,390 9,402 10 14,045 14,090 9,582 9,609 45 89 3 • • Scope of Work: • Rig up slick line.Test Lubricator to 3500 psi • Recover jet pump and standing valve V • Rig up eLine • Perforate selected zones • Rig up Slick Line • Set standing valve with PT bomb / • Set Jet Pump • Rig down. Flow well General Well Information: Reservoir Pressure/TVD: 4132 psi @ 9,609 TVD (.43 psi/ft) MASP : 3171 psi (.1psi/ft gas gradient) (assumes virgin pressure in new perfs) 4132 psi- (9609'well with .1 psi/ft gas) Wellhead Type/Pressure Rating: 13 5/8" 5M Wellhead/ 2 7/8" 5M tree Well Type: Oil Well Estimated Start Date: ASAP CIE Drilling Manager: CIE Sr. Drilling Engineer: CIE Production Manager: Conrad Perry Stephen Ratcliff David Kumar (907) 727-7404 (907)433-9738 (907) 433-3822 conrad.perry@Cooklnlet.net Stephen.Ratcliff@Cooklnlet.net David.Kumar@CookInlet.net Program 1. Mobilize crew and guns to West Mac 2. Conduct pre-job safety meeting with all Pollard and production personnel. 3. Shut-in WMRU-5. Lock out safety systems. Lock out power oil. Ensure SSSV is open. 4. Rig up slick line. Test Lubricator to 3500 psi - 5. Recover jet pump and standing valve. 6. Rig up eLine 4 • S 7. Perforate selected zones with 2 1/8"tubing guns 6spf/ 60 deg phased: Measured Depth Total Vertical Depth Top Base Top Base MD Feet Toal 13,512 13,524 9,264 9,271 12 13,548 13,554 "! 9,286 9,290 6 13,582 13,592 9,307 9,313 10 13,642 13,648 9,344 9,348 6 13,718 13,728 I 9,390 9,402 10 14,045 14,090 9,582 9,609 45 89 o Correlation log is HDS synthetic log dated XX/XX/XX based on triple combo LWD log. o Perf order is not critical. Maximize efficiency. o Monitor and record surface pressure after each shot run. 8. Rig down eLine. Release perf crew. 9. Rig up Slick Line. 10.Set standing valve with PT bomb 1 ° P ' s" 11.Set Jet Pump (C-ht T) 12. Rig down slick line. 13.Clear team ready for production. 14.Clear lock-outs 15. Flow well. Release slick line crew if all is ok. (-!3•-1 5 4•11IRU-5 Current Completion • 4/11/2016 Version 1.0 1 L 20" L-80 03'MD 133# Buttress 103'ND 13 3/8" L-80 2204'MD 68# Buttress 2151'TVD TOL 6,390' 9 5/8" L-80 6638'MD 47# Buttress 5011'TVD TOL @ 12,695' 7 5/8" L-80 12,858'MD 29.7# STL 8870'TVD PROPOSED PERF ADDS I 1 2 7/8"6.5#P-110 EUE Tubing-ID-2.441" Opti Sliding Sleeve-OD 3.2"-ID-2.313" Weatherford Jet Pump-OD-3.55"©13,352' f Jet Pump Cavity-OD-3.55"-ID-2.25" 5 1/2"Baker F-1 Packer 13,390' with Seal Assembly Hemlock Perforations WMRU 5 Existing Perfs.4/11/2016 ,. , MD MD TVD TVD WLEG @ 13,434 Top Base Top Base 13,485 13,500 9247.02 92566.61= PROPOSED PERFS 13,506 13,512 9260.02 92637 13,524 13,538 9271.19 9279.89 — 13,566 13,579 9297.35 9305.48 13,592 13,619 9313.57 9330.29 13,624 13,633 9333.38 9338.91 13,648 13,708 9348.11 9384.39 13,728 13,738 9396.22 9402.09 13,766 13,930 9418.33 9512.83 13,942 14,008 9519.92 9559.44 14,090 14,114 9609.41 9624.07 14,126 14,180 9631.40 9664.38 5 1/2"15.5#L-80 Hyd 511 14443'MD 9800'TVD Vii TD 14,450'MD/9835'TVD •RU-5 Proposed Completion • 4/11/2016 Peri Adds Version 1.0 J i 1 1. 20" L-80 _ 103'MD 133# Buttress 103'TVD r 3. 9 13 3/8" L-80 2204'MD 1 68# Buttress 2151'TVD 1, a „a 11111 7 5/8"TOL 6,390' '., 9 518" L-80 6638'MD 47# Buttress 5017'ND IO 4 s 'a 1" `1 5 1/2"TOL @ 12,695' 7 5/8"Liner L-80 12,858'MD 29.7# STL 8870'TVD 6. 1 d e 41 PROPOSED PERF ADDS r' 2 7/8"6.5#P-110 EUE Tubing-ID-2.441" 1110'®.110'®""k E Opti SlidingSleeve-OD 3.2"-ID-2.313" 13,512 13,524 9,264 9,271 12 t 13,548 13,554 9,286 9,290 j 6 Weatherford Jet Pump-OD-3.55"@ 13,352' 13,582 13,592 9,3079,313 10 a�.,z,.� Jet Pump Cavity-OD-3.55"-ID-2.25" 13,642 13,648 9,344 � 9,348 6 13,718 13,728 9,390 9,402 10 + !' 14,045 14,090 9,582 9,609 45 `1 , 5 1/2"Baker F-1 Packer 13,390' k tt, with Seal Assembly Hemlock Perforations a c7 4, t Existing Perfs.4/11/2016 i., MD TVD a ° WLEG©13,434 Top IBase Top (Base 13,485 13,500 9247.02 9256.61 PROPOSED PERFS 13,506 13,512 9260.02 9263.74 ;i r 13,524 13,538 9271.19 9279.89 13,566 13,579 9297.35 9305.48 g 13,592 13,619 9313.57 9330.29 13,624 13,633 9333.38 9338.91 13,648 13,708 9348.11 9384.39 13,728 13,738 9396.22 9402.09 13,766 13,930 9418.33 9512.83 ' 13,942 14,008 9519.92 9559.44 r 14,090 14,114 9609.41 9624.07 14,126 14,180 9631.40 9664.38 5 1/2"15.5#L-80 Hyd 511 Liner 114443'MDI 9800'ND , a. ,,t Ai: TD 14,450'MD/9835'ND Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ? ,il Number Hi. or ,i e PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original'- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. n Other, No/Type OVERSIZED Logs of various kinds Other COMMENTS: Scanned by: Beverly Mildred Daretha Lowell TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: Is~ • • UNSCANNED, OVERSIZED MATERIALS AVAILABLE: ~ ~' ~~ FILE # To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission ! 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279-1433 ~ Fax (907) 276-7542 • • SlfaffEE CIF A[LASELI 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 tkitiOLD JUN 2 4 201, Re: Safety Valve System Testing 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 1A (PTD 1951180) - West McArthur River Unit 2A (PTD 1931550) ( i - - . - st McArthur River Unit 5 (PTD 1980 70) - West McArthur ' ver Unit 6 ' 0 - Kustatan Field 1 (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, Cathy P Foers er Commissioner _ Cook Inlet Energy_ RECEIVED FEB 2 4 2010 February 24, 2010 Mr. Dan Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Dear Mr. Seamount, RE: Well Workover Completion Report Cook Inlet Energy, LLC. PTD No. 198-047 Sundry No. 309-435 ~1991ca ON & GH6 Cony. Commission A~di~ ';~~,;,"~n~i~l"`,~ ~d Zd~0 Dear Commissioner Seamount, Cook Inlet Energy, LLC hereby submits its Well Workover Completion Report for the work performed in working over its WMRU #5 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. David Hall ~ ~w,~ CE~ Attachments Cc: Alexey Sachivichik -Fairweather STATE OF ALASKA ALASK~L AND GAS CONSERVATION COMMISSI• REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Repair Well ~ Plug Perforations Stimulate Other Performed: Alter Casing ^ Pull Tubing ^~ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^~ Re-enter Suspended Well ^ 2. Operator Cook Inlet Energy, LLC. 4. Well Class Before Work: . Permit to Drill Number: Name: Development ^~ Exploratory ^ 198-047 3. Address: 4141 B Street, Suite 302, Anchorage, Alaska Stratigraphic^ Service ^ . API Number: O 99503 50-133- -0000 ~ ~ ~S r 7. Property Designation (Lease N ber): 8. Well Name and Number: \ ADL 0359111 1 West McArthur River Unit #5 9. Field/Pool(s): West McArthur River Oil Pool 10. Present Well Condition Summary: Total Depth measured 14,450' feet Plugs (measured) N/A feet true vertical 9,835' feet Junk (measured) N/A feet Effective Depth measured 14,317' feet Packer (measured) 13,390' feet true vertical 9,721' feet (true vertical) 9,195' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 103' 20" 103' 103' N/A N/A Surface 2,204' 13-3/8" 2,204' 2,151' 5,020 psi 2,260 psi Intermediate 6,638' 9-5/8" 6,638' 5,011' 6,870 psi 4,750 psi Intermediate Liner 6,468' 7-5/8" 12,868' 8,870' 6,890 psi 4,790 psi Production Liner 1,748' S-1 /2" 14,433' 9,800' 7,740 psi 6,280 psi Perforation depth: Measured depth: 13,485' - 14,180' True Vertical depth: 9,253' - 9,675' Tubing (size, grade, measured and true vertical depth): 2-7/8" L-80 13,433' 9,201' Packers and SSSV (type, measured and true vertical depth): Baker F-1 Packer 13,390' 9,194' 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: 500 117 1200 70 4000 Subsequent to operation: 560 131 1400 70 4000 13. Attachments: 4. 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 ^ GS OR ^ 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 / Signature ~~ /~ Phone 907-334-6745 Date 2/25/2010 RBDIy~~ 2 5 10~~~'~t~, Form 10-404 Revised 7/2009 2•Z %~ s-.CC, Submit Original Only > 3 , . -,:.~ . 01/07/2010 10:28 907276754 AO~CC • STATE OF ALASKA I~~ ALASKA OIL ANb OA8 CONSERVATION COI~NNBSION `'V APPLICATION FOR SUNDRY APPROVALS ~n s e~+ ~e ~Qn PACE 01 t ~'~~~~ rz~;o~z,p~g ~ ~~\ 1. Type of Request: Atam~n Sutlpend Opsr eFUabQaNK1 Pr3r'fa~abe Watvar 4thel' ^ ~ a • Pig Peru ^ . ^ Thne , ^ Cfatrpe approved program ^ Pu7 TubYg ~] Perforate New Pool ^ l~s•atter Suspended W1Y ^ 2.Opgoplor Nalco: 4. Cuner4 WeN Cklea: 6. Penult to Deed Number Cook MNet , LL:f; De+eNop~ntent ® E~bAboly ^ llbit! - 3. Addraes: ~ ^ 8arvke ^ @, API Number: 4141 B >M.. 8u1te 607; Attalloraoe, AK 55405 gg-1is~0iN~N0 - 7. If parfoeatlng, oknaat appregeh In pool(s) opened t-ylMe opatatbn to nsereet 8. We7 Name and Nundfp; property 7ne where owrterahlp ar IsndoNenra~ ate: NIA Spaohg 6soepBon Rao~lrad'I Yes ^ No ^ W. MaAr~r IMw- UNt #ib 9. PtopeRy Deai~tiort: 10. K8 Eknafbn (!1): t1. hiNWPaoI(a): ADL. 0.1N111 . 143' 1K McJlelfwt Illear i / ~ 12. PRlalNT t#IlLL CONIITIOkI SUMMARY e3 , r~ TaW Depth MD (It): Total Oapth TVO (1h: ttfiotlvit Oeplh MO (ft): Ef1~Na CapRh 1'VD (ft): Pheps (rtateaut~d): .lUnk (~: 14+450' 0.0ag' ` t4,3'1T l.7T1• N/A NMI Geleeg Leeegth $i5e MD TtID Bveat Co11Mla~e Condtl~ ~' 3D' 103' 1b' NtA NIA Sutfeoe 9.204' 13.3f5" 7,x04• 3,151' 4.06:0 Psl 2.310 psi IAOernredgda 5,~' O.SM" e;ar SA11' S,ti70 Pd 4y7N pal ~tarmadYls Lhw gAq' f~A" 19,555' 5,570' 8,640 psi 4,750 pq Prod Uhst 1,745' S-1/Z" 14,443' BA00' 7,745 pet g,~ lyd Pwlbradon Depth Mt7 (R): Perfora0on Oepth Ti-D (ft): Ting Star: Tubing Geidr Tutliltg MD (It): 16.044' •14,100' / 5,=58' • 0,N5' 3 7M" L•50 13,481' PeolOrla emi 88SY Type: ' ' ~d SSSV MO (R): ' / Pkt: tlakar 4p0 R , Ne 8BS11 ~ d 13,x . ~ pgp~pq Sullltrlaly et p~p~ © 14. WiN Ckiaa alter 17MMad' ^ BOP Shebh © - ^ d ®~ lNuvl~ ^ 1 S. EaSnaded Data trot 18. Wet 8lek~s alter proposed work: ~ 1I4I>DD10 ~ Ol ~ • Ge. ^ pq ^ AbandOnsd ^ 17. YarbM Approval Dater Commisabn Repns~atlw: WAG ^ GINJ ^ WINJ ^ WOSPI, ^ 1!!.1 hentby oatly tl~t the ronpoing b true and oomeot to the t~ ~ my krtvrrlecipa. CaeOeot Darla Mae 334.5744 Prt~rd Name Owld @NS Tk~ /O7 " oa ~ e'1O D CEp ®~ Phone Data ~{ 434/745 COMMISSION UBB ONt.Y Cw~Ons of epprovsl Netify Commbelon ea that a npraa~abw may veitr~ese Nutnhor: ,~~~ ~~} Plug fr~tijy ^ BOP Ttet ~ ~ InEeprtly Tact [] loeA!(on Cigrarroe ^ .. • . .-: ~~ Other: ( S~ ~~~>~ lA ~O'JJ ~lrrb . ...,f, ~- • ~ , 6~eequent Fomt ~ ,~„ , ; ~ , APPROVEp 8Y Approved ~ COMMIStdONER TWE CONNMISSION Oats: ~p?~~'' c~ .. ~: t ~J • WMRU #5 Completion Schematic 20" 133#, L-80 BTC @103' MD, 103' TVD 13 3/8" 68#, L-80 BTC @ 2204' MD, 2151' TVD TOL @ 6,390' MD 9 5/8" 47#, L-80 BTC @ 6638' MD, 5011' TVD TOL @ 12,695' MD 7-5/8" 29.7#, L-80 STL @ 12,858' MD, 8870' ND SI. Sleeve with X profile @ 13,351'MD Packer @ 13,390' MD 2-7/8" P-110, 6.5# Tbg Tail @ 13,433.9' MD Mill Shoe (WLEG) @ 13,433.9' Perforations: 13,485'-14,180' MD 5-1/2" 15.5#, L-80 Hyd 511 ~ 14,443' MD, 9,800' TVD TD 14,450' MD, 9,835' TVD • • WMRU #5 Final COMPLETION SUMMARY Date 2/19/2010 WELL # WEST McAURTHER RIVER #5 TUBING SIZE/GRADE/THREAD 2-7/8" L80 8rd EUE _ Cook Inlet Energy_ TUBING WT/FT 6.5# / ft Middle of Baker F-1 Packer 13391' TOP OF TUBING HANGER AT (RKB) 12.93 ft Connections NO ITEM Top Bottom OD ID LENGTH TOP BOTTOM Mule Shoe WLEG EUE n/a 4 2.347 0.75 13,433.90 13,434.65 1TP Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.53 13,402.37 13,433.90 Seal Bore Crossover Baker EUE 4.45 2.347 0.64 13,401.73 13,402.37 Seal Bore Extension PBR) Baker Baker 3.79 2.980 9.37 13,392.36 13,401.73 B-Guide Baker Baker 4.56 2.980 0.58 13,391.78 13,392.36 Baker Model F-1 Packer n/a Baker 4.56 2.980 1.78 13,390.00 13,391.78 Seal Assembly 9.46' w/WLEG Baker Baker 3.000 2.370 0.00 13,390.00 13,390.00 Locator Sub EUE Baker 3.000 2.380 1.79 13,388.21 13,390.00 1 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 13,356.53 13,388.21 Weatherford S. Valve /Jet Pump w/ XO WOT EUE 3.550 2.250 1.31 13,355.22 13,356.53 OPTI Slidin Sleeve WOT WOT 3.200 2.313 3.90 13,351.32 13,355.22 Crossover EUE WOT 3.500 2.370 0.80 13,350.52 13,351.32 2 Joint 2-718" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 13,318.86 13,350.52 3 Joint 2-718" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 13,287.21 13,318.86 4 Joint 2-718" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 13,255.53 13,287.21 5 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.00 13,224.53 13,255.53 6 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 13,192.87 13,224.53 7 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 13,161.22 13,192.87 8 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 13,129.52 13,161.22 9 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 13,097.84 13,129.52 10 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 30.95 13,066.89 13,097.84 11 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.73 13,035.16 13,066.89 12 Joint 2-718" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.63 13,003.53 13,035.16 13 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.64 12,971.89 13,003.53 14 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.62 12,940.27 12,971.89 15 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.72 12,908.55 12,940.27 16 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 12,876.85 12,908.55 17 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.71 12,845.14 12,876.85 18 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 12,813.49 12,845.14 19 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.00 12,782.49 12,813.49 20 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.75 12,750.74 12,782.49 21 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 12,719.09 12,750.74 22 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 12,687.43 12,719.09 23 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 12,655.73 12,687.43 24 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.64 12,624.09 12,655.73 25 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 12,592.43 12,624.09 26 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 12,560.73 12,592.43 27 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.62 12,529.11 12,560.73 28 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.60 12,497.51 12,529.11 29 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 30.32 12,467.19 12,497.51 30 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 12,435.54 12,467.19 31 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.62 12,403.92 12,435.54 32 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.67 12,372.25 12,403.92 33 Joint 2-718" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.64 12,340.61 12,372.25 34 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 12,308.91 12,340.61 35 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 30.95 12,277.96 12,308.91 36 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 12,246.26 12,277.96 37 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 12,214.61 12,246.26 38 Joint 2-7/8" 6.5# L-80 Tb EUE 2.875 2.440 31.64 12,182.97 12,214.61 39 Joint 2-718" 6.5# L-80 Tb EUE 2.875 2.440 31.63 12,151.34 12,182.97 40 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 12,119.64 12,151.34 i v WMRU #5 Final COMP LETION SUM MARY Date 2/19/2010 41 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 12,087.99 12,119.64 42 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.64 12,056.35 12,087.99 43 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.72 12,024.63 12,056.35 44 Joint2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.60 11,993.03 12,024.63 45 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.00 11,962.03 11,993.03 46 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 11,930.33 11,962.03 47 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.62 11,898.71 11,930.33 48 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 11,867.03 11,898.71 49 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31,66 11,835.37 11,867.03 50 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.71 11,803.66 11,835.37 51 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.00 11,772.66 11,803.66 52 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.72 11,740.94 11,772.66 53 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 11,709.24 11,740.94 54 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.71 11,677.53 11,709.24 55 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.72 11,645.81 11,677.53 56 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.60 11,614.21 11,645.81 57 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 11,582.56 11,614.21 58 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 11,550.86 11,582.56 59 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.50 11,519.36 11,550.86 60 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.53 11,487.83 11,519.36 61 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.71 11,456.12 11,487.83 62 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.63 11,424.49 11,456.12 63 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.87 11,392.62 11,424.49 64 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.73 11,360.89 11,392.62 65 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 11,329.19 11,360.89 66 Joint2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.04 11,298.15 11,329.19 67 Joint2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 11,266.45 11,298.15 68 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.59 11,234.86 11,266.45 69 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 11,203.18 11,234.86 70 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.62 11,171.56 11,203.18 71 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.63 11,139.93 11,171.56 72 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.73 11,108.20 11,139.93 73 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 11,076.52 11,108.20 74 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.63 11,044.89 11,076.52 75 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 11,013.23 11,044.89 76 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.63 10,981.60 11,013.23 77 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 10,949.95 10,981.60 78 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 10,918.27 10,949.95 79 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.63 10,886.64 10,918.27 80 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.62 10,855.02 10,886.64 81 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 10,823.36 10,855.02 82 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 10,791.71 10,823.36 83 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 10,760.05 10,791.71 84 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 10,728.40 10,760.05 85 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 .2.440 31.66 10,696.74 10,728.40 86 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.67 10,665.07 10,696.74 87 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.62 10,633.45 10,665.07 88 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.71 10,601.74 10,633.45 89 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.61 10,570.13 10,601.74 90 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.62 10,538.51 10,570.13 91 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 10,506.83 10,538.51 92 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.63 10,475.20 10,506.83 93 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.67 10,443.53 10,475.20 94 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.71 10,411.82 10,443.53 95 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 10,380.12 10,411.82 96 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 10,348.44 10,380.12 97 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.56 10,316.88 10,348.44 98 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 29.95 10,286.93 10,316.88- 99 Joint 2-7/8" 6.5# L-80 Tb EUE 2.875 2.440 31.64 10,255.29 10,286.93 100 Joint 2-7/8" 6.5# L-80 Tb EUE 2.875 2.440 31.67 10,223.62 10,255.29 101 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 10,191.92 10,223.62 i WMRU #5 Final COMP LETION SUM MARY Date 2/19/2010 102 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.55 10,160.37 10,191.92 103 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 30.62 10,129.75 10,160.37 104 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 10,098.07 10,129.75 105 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 10,066.41 10,098.07 106 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 10,034.76 10,066.41 107 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.60 10,003.16 10,034.76 108 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.77 9,971.39 10,003.16 109 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 9,939.71 9,971.39 110 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.71 9,908.00 9,939.71 111 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.60 9,876.40 9,908.00 112 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.71 9,844.69 9,876.40 113 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.67 9,813.02 ,9,844.69 114 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 9,781.34 9,813.02 115 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 9,749.68 9,781.34 116 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 29.93 9,719.75 9,749.68 117 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.72 9,688.03 9,719.75 118 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.00 9,657.03 9,688.03 119 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.69 9,625.34 9,657.03 120 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.60 9,593.74 9,625.34 121 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.00 9,562.74 9,593.74 122 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 9,531.09 9,562.74 123 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.73 9,499.36 9,531.09 124 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.60 9,467.76 9,499.36 125 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.58 9,436.18 9,467.76 126 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 9,404.48 9,436.18 127 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.64 9,372.84 9,404.48 128 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 9,341.14 9,372.84 129 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.64 9,309.50 9,341.14 130 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.63 9,277.87 9,309.50 131 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 9,246.19 9,277.87 132 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.62 9,214.57 9,246.19 133 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.63 9,182.94 9,214.57 134 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 9,151.26 9,182.94 135 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.00 9,120.26 9,151.26 136 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 9,088.60 9,120.26 137 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 9,056.92 9,088.60 138 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.69 9,025.23 9,056.92 139 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.62 8,993.61 9,025.23 140 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 8,961.96 8,993.61 141 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.67 8,930.29 8,961.96 142 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 8,898.59 8,930.29 143 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.58 8,867.01 8,898.59 144 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 8,835.35 8,867.01 145 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 29.18 8,806.17 8,835.35 146 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.67 8,774.50 8,806.17 147 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.57 8,742.93 8,774.50 148 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.62 8,711.31 8,742.93 149 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.00 8,680.31 8,711.31 150 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.62 8,648.69 8,680.31 151 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.67 8,617.02 8,648.69 152 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.67 8,585.35 8,617.02 153 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 8,553.67 8,585.35 154 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.63 8,522.04 8,553.67 155 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.62 8,490.42 8,522.04 156 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.67 8,458.75 8,490.42 157 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 8,427.05 8,458.75 158 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.69 8,395.36 8,427.05 159 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.58 8,363.78 8,395.36 160 Joint 2-7/8" 6.5# L-80 Tb EUE 2.875 2.440 31.62 8,332.16 8,363.78 161 Joint 2-7/8" 6.5# L-80 Tb EUE 2.875 2.440 31.60 8,300.56 8,332.16 162 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 8,268.88 8,300.56 • WMRU #5 Final COMP LETION SUM MARY Date 2/19/2010 163 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.63 8,237.25 8,268.88 164 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.64 8,205.61 8,237.25 165 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 8,173.91 8,205.61 166 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 8,142.26 8,173.91 167 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.67 8,110.59 8,142.26 168 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 8,078.89 8,110.59 169 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.69 8,047.20 8,078.89 170 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 8,015.54 8,047.20 171 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 7,983.88 8,015.54 172 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 7,952.23 7,983.88 173 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 7,920.53 7,952.23 174 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 7,888.88 7,920.53 175 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.67 7,857.21 7,888.88 176 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.64 7,825.57 7,857.21 177 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.64 7,793.93 7,825.57 178 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.62 7,762.31 7,793.93 179 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.32 7,730.99 7,762.31 180 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.67 7,699.32 7,730.99 181 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.60 7,667.72 7,699.32 182 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.63 7,636.09 7,667.72 183 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 7,604.41 7,636.09 184 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.62 7,572.79 7,604.41 185 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.69 7,541.10 7,572.79 186 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.63 7,509.47 7,541.10 187 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 7,477.82 7,509.47 188 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 7,446.12 7,477.82 189 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.69 7,414.43 7,446.12 190 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.69 7,382.74 7,414.43 191 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 7,351.06 7,382.74 192 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.69 7,319.37 7,351.06 193 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 7,287.67 7,319.37 194 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.63 7,256.04 7,287.67 195 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.64 7,224.40 7,256.04 196 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.64 7,192.76 7,224.40 197 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 7,161.10 7,192.76 198 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.63 7,129.47 7,161.10 199 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.59 7,097.88 7,129.47 200 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 7,066.20 7,097.88 201 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.63 7,034.57 7,066.20 202 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 7,002.91 7,034.57 203 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.62 6,971.29 7,002.91 204 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.69 6,939.60 6,971.29 205 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.71 6,907.89 6,939.60 206 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 6,876.19 6,907.89 207 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.59 6,844.60 6,876.19 208 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.60 6,813.00 6,844.60 209 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 6,781.30 6,813.00 210 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.63 6,749.67 6,781.30 211 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.69 6,717.98 .6,749.67 212 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.67 6,686.31 6,717.98 213 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 6,654.65 6,686.31 214 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.67 6,622.98 6,654.65 215 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.60 6,591.38 6,622.98 216 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 6,559.73 6,591.38 217 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.63 6,528.10 6,559.73 218 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.69 6,496.41 6,528.10 219 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 6,464.71 6,496.41 220 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 6,433.01 6,464.71 221 Joint 2-7/8" 6.5# L-80 Tb EUE U 2.875 2.440 31.67 6,401.34 6,433.01 222 Joint 2-7/8" 6.5# L-80 Tb EUE 2.875 2.440 31.66 6,369.68 6,401.34 223 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 6,338.00 6,369.68 i WMRU #5 Final COMP LETION SUM MARY Date 2/19/2010 224 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.64 6,306.36 6,338.00 225 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.61 6,274.75 6,306.36 226 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.62 6,243.13 6,274.75 227 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 6,211.47 6,243.13 228 -Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.67 6,179.80 6,211.47 229 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 29.14 6,150.66 6,179.80 230 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 6,119.00 6,150.66 231 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.64 6,087.36 6,119.00 232 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 6,055.66 6,087.36 233 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.67 6,023.99 6,055.66 234 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 5,992.33 6,023.99 235 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 5,960.63 .5,992.33 236 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 5,928.98 5,960.63 237 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 5,897.28 5,928.98 238 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.48 5,865.80 5,897.28 239 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.05 5,834.75 5,865.80 240 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.62 5,803.13 5,834.75 241 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.00 5,772.13 5,803.13 242 Joint 2-7/8" 8.5# L-80 Tb EUE EUE 2.875 2.440 31.69 5,740.44 5,772.13 243 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 5,708.76 5,740.44 244 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.64 5,677.12 5,708.76 245 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.00 5,646.12 5,677.12 246 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 5,614.42 5,646.12 247 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 5,582.77 5,614.42 248 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.64 5,551.13 5,582.77 249 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 5,519.43 5,551.13 250 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.63 5,487.80 5,519.43 251 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.60 5,456.20 5,487.80 252 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.62 5,424.58 5,456.20 253 Joint 2-7/8" 8.5# L-80 Tb EUE EUE 2.875 2.440 31.65 5,392.93 5,424.58 254 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.72 5,361.21 5,392.93 255 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 5,329.55 5,361.21 256 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 30.20 5,299.35 5,329.55 257 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.63 5,267.72 5,299.35 258 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 5,236.07 5,267.72 259 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 5,204.39 5,236.07 260 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 30.38 5,174.01 5,204.39 261 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 5,142.31 5,174.01 262 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.71 5,110.60 5',142.31 263 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.69 5,078.91 5,110.60 264 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 5,047.21 5,078.91 265 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 30.90 5,016.31 5,047.21 266 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 4,984.65 5,016.31 267 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 4,952.95 4,984.65 268 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 4,921.30 4,952.95 269 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.06 4,890.24 4,921.30 270 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 4,858.59 4,890.24 271 Joint 2-7/8" 6.5# L-80 Tb EUE EUE -2.875 2.440 31.08 4,827.51 4,858.59 272 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 4,795.81 4,827.51 273 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.55 4,764.26 4,795.81 274 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.62 4,732.64 4,764.26 275 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.62 4,701.02 4,732.64 276 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 4,669.32 4,701.02 277 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.00 4,638.32 4,669.32 278 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 4,606.67 4,638.32 279 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 4,574.97 4,606.67 280 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.69 4,543.28 4,574.97 281 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.62 4,511.66 4,543.28 282 Joint 2-7/8" 6.5# L-80 Tb EUE 2.875 2.440 31.70 4,479.96 4,511.66 283 Joint 2-7/8" 6.5# L-80 Tb EUE 2.875 2.440 31.66 4,448.30 4,479.96 284 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 4,416.64 4,448.30 WMRU #5 Final COMP LETION SUM MARY Date 2/19/2010 285 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.76 4,384.88 4,416.64 286 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.63 4,353.25 4,384.88 287 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.60 4,321.65 4,353.25 288 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.67 4,289.98 4,321.65 289 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 4,258.28 4,289.98 290 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.60 4,226.68 4,258.28 291 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 4,195.03 4,226.68 292 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 4,163.35 4,195.03 293 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.05 4,132.30 4,163.35 294 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 4,100.60 4,132.30 295 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 4,068.95 4,100.60 296 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.60 4,037.35 4,068.95 297 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 4,005.65 4,037.35 298 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 3,974.00 4,005.65 299 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.63 3,942.37 3,974.00 300 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 3,910.72 3,942.37 301 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 3,879.02 3,910.72 302 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 3,847.36 3,879.02 303 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 3,815.66 3,847.36 304 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 3,784.01 3,815.66 305 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.62 3,752.39 3,784.01 306 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.67 3,720.72 3,752.39 307 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.69 3,689.03 3,720.72 308 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 3,657.35 3,689.03 309 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.08 3,626.27 3,657.35 310 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 3,594.57 3,626.27 311 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.05 3,563.52 3,594.57 312 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 3,531.82 3,563.52 313 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.72 3,500.10 3,531.82 314 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.00 3,469.10 3,500.10 315 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 3,437.42 3,469.10 316 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.72 3,405.70 3,437.42 317 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 3,374.02 3,405.70 318 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 3,342.36 3,374.02 319 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.64 3,310.72 3,342.36 320 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 3,279.07 3,310.72 321 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.05 3,248.02 3,279.07 322 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 3,216.32 3,248.02 323 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.67 3,184.65 3,216.32 324 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 3,152.97 3,184.65 325 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.05 3,121.92 3,152.97 326 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 3,090.24 3,121.92 327 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 3,058.59 3,090.24 328 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 3,026.91 3,058.59 329 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 2,995.21 3,026.91 330 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 2,963.53 2,995.21 331 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.63 2,931.90 2,963.53 332 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.62 2,900.28 2,931.90 333 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.72 2,868.56 2,900.28 334 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 2,836.88 2,868.56 335 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.71 2,805.17 2,836.88 336 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 2,773.49 2,805.17 337 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.69 2,741.80 2,773.49 338 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 2,710.12 2,741.80 339 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.71 2,678.41 2,710.12 340 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 2,646.71 2,678.41 341 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.58 2,615.13 2,646.71 342 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.63 2,583.50 2,615.13 343 Joint 2-7/8" 6.5# L-80 Tb EUE 2.875 2.440 31.00 2,552.50 2,583.50 344 Joint 2-7/8" 6.5# L-80 Tb EUE 2.875 2.440 31.70 2,520.80 2,552.50 345 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.69 2,489.11 2,520.80 WMRU #5 Final COMPLETION SUM MARY Date 2/19/2010 346 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.63 2,457.48 2,489.11 347 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 2,425.82 2,457.48 348 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.60 2,394.22 2,425.82 349 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 2,362.54 2,394.22 350 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.72 2,330.82 2,362.54- 351 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.71 2,299.11 2,330.82 352 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.69 2,267.42 2,299.11 353 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 2,235.72 2,267.42 354 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 2,204.02 2,235.72 355 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.71 2,172.31 2,204.02 356 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.69 2,140.62 2,172.31 357 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.52 2,109.10 2,140.62 358 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 2,077.42 2,109.10 359 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 2,045.74 2,077.42 360 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.67 2,014.07 2,045.74 361 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 1,982.41 2,014.07 362 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 1,950.75 1,982.41 363 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.08 1,919.67 1,950.75 364 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.72 1,887.95 1,919.67 365 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 1,856.27 1,887.95 366 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 1,824.61 1,856.27 367 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 1,792.91 1,824.61 368 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 1,761.23 1,792.91 369 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.58 1,729.65 1,761.23 370 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 1,697.97 1,729.65 371 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 1,666.29 1,697.97 372 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.64 1,634.65 1,666.29 373 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 1,602.95 1,634.65 374 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.06 1,571.89 1,602.95 375 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 1,540.19 1,571.89 376 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 1,508.51 1,540.19 377 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 1,476.83 1,508.51 378 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.61 1,445.22 1,476.83 379 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 1,413.54 1,445.22 380 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 1,381.89 1,413.54 381 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.63 1,350.26 1,381.89 382 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 1,318.56 1,350.26 383 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.63 1,286.93 1,318.56 384 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.60 1,255.33 1,286.93 385 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.69 1,223.64 1,255.33 386 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 1,191.96 1,223.64 387 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 1,160.30 1,191.96 388 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 1,128.62 1,160.30 389 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 1,096.94 1,128.62 390 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 1,065.24 1,096.94 391 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.05 1,034.19 1,065.24 392 Joint2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.72 1,002.47 1,034.19 393 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.58 970.89 1,002.47 394 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.64 939.25 970.89 395 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.64 907.61 939.25 396 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.60 876.01 907.61 397 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.62 844.39 876.01 398 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.59 812.80 844.39 399 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.60 781.20 812.80 400 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.58 749.62 781.20 401 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 717.96 749.62 402 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 686.26 717.96 403 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 654.61 686.26 404 Joint 2-7/8" 6.5# L-80 Tb EUE 2.875 2.440 31.07 623.54 654.61 405 Joint 2-7/8" 6.5# L-80 Tb EUE 2.875 2.440 31.03 592.51 623.54 406 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.03 561.48 592.51 WMRU #5 Final COMPLETION SUM MARY Date 2/19/2010 407 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 529.82 561.48 408 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.05 498.77 529.82 409 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.63 467.14 498.77 410 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 435.44 467.14 411 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.67 403.77 435.44 412 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.70 372.07 403.77 413 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.60 340.47 372.07 414 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 308.82 340.47 415 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 277.14 308.82 416 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.62 245.52 277.14 417 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.69 213.83 245.52 418 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.65 182.18 213.83 419 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 150.52 182.18 420 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.68 118.84 150.52 421 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.67 87.17 118.84 422 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.66 55.51 87.17 423 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.69 23.82 55.51 424 Pup Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 6.20 17.62 23.82 425 Pup Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 3.70 13.92 17.62 13.92 13.92 13.92 13.92 Vetco Tubin Han er top threads are EUE 0.80 13.12 13.92 13.12 13.12 WS #1 12.95' RK 12.95 0.17 13.12 BHA Total Length 13434.48 Note: Ran as an assembly set on WL by Schlumberger Total of 424 full joints were run. Length 9.46' not included in overall tally Locator sub landed 1' hi h off pkr. Acutal length 0.79' Page 8 of 8 • Cook Inlet Energy_ West McArthur River Unit #5 Operation Summary • ~ January 28, 2010 -Finish BOP nipple up. Finish Quadco PVT installation. Work on steam system and stair modification. January 29, 2010 -Check out koomey unit and function test BOP. Level derrick and retighten guide lines. Perform 250/3000 psi test on blind rams against choke manifold -good test. Rig up and take produced water on in pits, 240 bbls. January 30, 2010 -Pre-test BOP's, annular pressure control valve and annular Barksdale valve are not working correctly. Everything else tested good. Rig up test joint with Weatherford floor valves and prepare to test. Temporarily replaced main air compressor with portable Sullair compressor. January 31, 2010 -Continue testing BOPE. Problem testing annular preventer. Nipple down flow line/riser. Nipple down and replace annular preventer. ROPE test is witnessed by AOGCC's John Crisp. February 1, 2010 -Finalize BOPE testing. Perform drilling line total change/slip. Experienced major torque/twist on blocks, work on taking twist out. Set herculite for LD machine, spot same and pipe racks. Get lines ready to run mud pumps to circulate. RU floor for pulling tubing. February 2, 2010 -Prep to fill the hole. Pull test plug, observe well and PU/MU 2 x 2-7/8" EUE pup joints and pump in swivel. Circulate well down tubing /out annulus until clean. Prepare to pull on tubing, back out LDS and pull 110K on tubing. String parted 117 joints down (3,676' TOF). Monitor well, inspect derrick and correct some issues. RU power tongs and POOH / LD tubing. Clean rig floor for fishing operation. February 3, 2010 - PU and RIH with 119 joints of 2-7/8" work string. Tag fish at 3,692'. Unable to catch fish. TOH. Inspect fishing tool. MU new BHA and TIH 59 stands plus one single. NU pump-in swivel and circulate well. February 4, 2010 -Work over and latch fish at 3,706'. RU Schlumberger Wireline. Run 2-1/8" gauge ring. Stopped at 6,110'. Run 1-11/16" gauge ring -stopped at the same place 6,110'. Run 2-1/8" jet cutter and cut tubing at 6,082'RKB. POOH, RD SLB Wireline. POOH with fish. • February 5, 2010 - LD tubing fish, dress fishing tool. RIH with 59 stands and 1 single from derrick. PU power swivel, RU attachments. PU and RIH 79 tubing singles from pipe rack. Wash through some sticky spots with pump-in swivel. February 6, 2010 -CBU at 6,082'. MU pump-in sub, work string-and mill over tubing stump. Catch fish. Set back pump-in sub, pull on fish - no movement. RU Schlumberger Wireline, run 1-11/16" and 2-1/8"gauge rings with pipe in tension at 130K and 145K to 9,754'. RIH with 2-1/8" jet cutter. February 7, 2010 -Cut 2-7/8" tubing at 9,719'. POOH, RD wireline. Circulate well at 9 bpm. POOH standing back work string. LD tubing fish. Test BOPE. Test witness waived by AOGCC~s John Crisp. February 8, 2010 -Finish testing BOPE. MU fishing assembly #4 and RIH. Tag TOF at 9,733'. Mill top of the fish. PU and circulate adding Super Slick. Latch on to the fish and confirm - caught. SD in slips, re-test Kelly valve per AOGCC requirement. RD power swivel and set back. Latch onto string and pull on fish. February 9, 2010 -Jar loose seal assembly, observe well. Establish 38 bbls of fluid loss to perforations. PU power swivel, back off fish. Mix and pump down HEC pill. Latch onto fish, pull seals from packer. Observe well -took another 2 bbls of fluid. POOH 13 stands. Hole static. POOH, LD overshot and fish. February 10, 2010 -POOH with fished tubing, pump assembly and seal assembly. MU milling assembly. RIH with 308 joints of P110 tubing and 65 joints of 2-7/8" drill pipe. February 11, 2010 -RIH to to oR f the packer. PU Dower swivel. check weights. Mill out packer. Mix, pump and spot 25 bbls of HEC pill. POOH wet. February 12, 2010 -POOH with milling assembly and LD. PU spear assembly. TIH to top of the fish. Push fish down 1 single plus 6' and caught the fish. POOH, monitoring well. February 13, 2010 -POOH to 12,685', drop ball, shear pump out sub. Observe well - flowina. CBU, spot 45 bbl of HEC pill on bottom. POOH with packer and gun fish. February 14, 2010 -Test BOPE. Test witness waived by AOGCC~s Chuck Shieve. Set wear ring. MU scraper assembly, TIH. Tag at 14,126', wash two singles in to 14,188'. February 15, 2010 -Wash to 14,250', pump 45 bbls of HEC sweep, continue CBU. Spot biocide pill on bottom. POOH laying down DP. Started pulling tight at 17 joints out. Circulate, spot HEC pill and CBU again with sweep. POOH. Observe well losses - 3.2 bbl/hr. February 16, 2010 - TOH standing back all pipe in derrick. RD flow nipple and RU shooting flange and Schlumberger wireline to run guns. Make 3 successful gun runs and perforate intervals: 13,566' -13,579', 13,506' - 13,512', 13,485' - 13,500'. RD Schlumberger shooting equipment and RU flow nipple. RU to run Baker packer. PU/MU single tubing joint with mule shoe on packer. MU Schlumberger running tool to top of the packer. • February 17, 2010 -Observe well -losses 0.6 bbl/hr. Re-head wireline. RIH with packer. Set Baker F-1 packer top at 13,390'. POOH. RD SLB wireline. PU DC~s and 12 stands of drill pipe, RIH. POH and LD drill pipe. RIH with P110 tubing. POH and LD tubing. February 18. 2010 -Finish LD DP and DC~s. Pull wear ring, clear rig floor, clean up rig. RU Weatherford hydraulic tongs. PJSM. PU seal assembly and locator sub on the bottom of first tubing joint.lldU standing valve and jet pumpseats, sliding sleeve (closed position) with XO on top of the same joint of tubing. RIH picking up tubing singles off pipe skate. February 19, 2010 -Continue RIH. PU tubing singles off pipe skate from joint #190 to joint #360. Finish running tubing with 423 joints and 2 pups for space out. Land tubing hanger, test annulus to 1000 psi -good. Test 2-7/8". 6.5#. P110 tubing to 4,500 psi for 30 minutes -good. Suck out cellar, start emptying pits. February 20, 2010 - RU Pollard slick line, RIH and shift sliding sleeve open. POOH, RD Pollard. ND BOPE, move choke house, trip tank and sub bases. ND BOP~s, NU and test production tree to 5,000 psi -good. Continue RD the rig while RU production lines and place well on line. February 21, 2010 - RDMO AWS #1. Pumping on well to de-water annulus and start bringing well on. • WMRU ~ WELL COMPLETION CUSTOMER: FORCENERGY DRAWING No. - APPROVED BY: - 000NTRY: USA FlELD: MCARIHUR RIVER DRAWN BY: KEN LUCKEY QUOTATION NO. - WELL NO DATE: 11/01/2000 ~~ ~~ xi°u°i x^s Baker Qil Tools MAX. O.D. MIN. I.D. S yEMATIC 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 MAIERIAL• 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 1HREADS: 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 a 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/B TNREADS:EUE 8 RD MATERIAL• L-80 O S-22 SNAP RELEASE ASSEMBLY SIZE: 40-30 SEAL ASSY THREAOS:EUE 89 RD BOX UP MATERIAL- 4140 18-22 RC 80 KSI PRODUCT N0: 444-55 NAP LATCH ASSEMBLE IS SPACED OUT 2' IS SET ON MARELING MEASUREMENTS O TH IS 20.52' DEEPER THAN NARELINE 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 SEALBORE SIZE: 40-30 MATERIAL• 4140 18-22 RC BO KSI PRODUCT N0:299-69 1U81NG SIZE: 2-7/8 THREADS: EUE 8 RO 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 NO: DEPTH BOTTOM 31.12 14079.74 3.82 4110:86 14114.78 1228 4094.2E 2.36 9.32 .60 32.20 14106.54 2.60 114140.98 2.60 14140.98 .85 14143.58 4144.43 • • ~ r 4 f P k p 2h ~ 4 a CPP NC ~ ~ r k' I ~ ~ ~) S ~ ~~ 4 ~ ~ ~ '; ~ ~ SEAN PARNELL, GOVERNOR F ~. Y 4 i 1" ~ ~ ~ U N N ~. ~ '~'~ f $ y , ~4 4 ' k I' ALA58iA OII. A1~TD GAS ~ ,, ..333 W. 7th AVENUE, SUITE 100 CO1~T5ERVA'1`IO1~T COM1~II55~Oi~T -_..r` __ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 ~' FAX (907) 276-7542 Mr. David Hall CEO Cook Inlet Energy ~y~,~y~-~`~:~ ~ ~`~ ,;~ a ~ (~'ja~ 4141 B Street, Suite 302 Anchorage, Alaska 99503 0~ Re: W. McArthur River, W. McArthur River Oil Pool, ~~ W. McArthur River Unit #5 \ ~, Sundry Number: 309-435 ,/~ l 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 ~~ y 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 #5 Pull-Replace Tubing operations Dear Mr. Seamount, ~~~~E~ Li ~)~.Cw 2 ~ 2~~J9 `~ ~~aska qil ~~s ~~ns. Cp~tission ~~!~i~~r The West McArthur River Unit #5 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, E~J ~c%~ David Hall CEO -Cook Inlet Energy Attachments: 10-403 Application for Sundry Approval Summary workover procedure Current completion schematic ~'`~~ I~ STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMIS ~'t/ APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 G \\O l L~30~Z00~ ~~\~~~ 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Pertorate ^/ - Waiver ^ Other ^ Alter casing ^ Repair well ^~ ~ Plug Pertorations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^~ Pertorate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Cook Inlet Energy, LLC Development ^ Exploratory ^ 198-047 3. Address: Stratigraphic ^ Service ^ 6. API Number: 4141 B St., Suite 302, Anchorage, AK 99503 50-133-20486-0000 7. If pertorating, 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 #5 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 0359111 ~ 163' ~ W. McArthur River [/r ~ ~~, 12. PRESENT WELL CONDITION SUMMARY f2 • z•~. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14,450' 9,835' 14,317' 9,721' N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 103' 20" 103' 103' N/A N/A Surtace 2,204' 13-3/8" 2,204' 2,151' 5,020 psi 2,260 psi Intermediate 6,638' 9-5/8" 6,638' 5,011' 6,870 psi 4,750 psi Intermediate Liner 6,468' 7-5/8" 12,858' 8,870' 6,890 psi 4,790 psi Production Liner 1,748' 5-1/2" 14,443' 9,800' 7,740 psi 6,280 psi Pertoration Depth MD (ft): Pertoration Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13,524' - 14,180' / 9,299' - 9,665' 2-7/8" L-80 13,469' Packers and SSSV Type: P ' ' Packers and SSSV MD (ft): ' kr: Baker 4530 F , No SSSV Pkr at 13,469 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: 1/5!2010 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 334-6745 Printed Name David Hall Title ~,~ - ,~2 ~ a?o o p' CEO Signature ~ Phone Date ~ 334-6745 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ,30 ,~ ~~/',~ Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ 'p Other: ($S~ PO~F fD ;000 ~i.G "' ~'~ 1! 1. r~i,~'~i '~~+IIISk~ p~ "~' ~Q.~~' $; - ilYt1tT11S~1at Subsequent Form quire ~ ~ [~ , ~ ~fRr-:~¢p~p~~ /~ ~ ~,~ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ~ s7 `~! .-e Form 10-403 Revised 06!2006 , ~~ r ~ L~ ~~ R~3LA115 JAN ' 21~1~ ~iP/' ~"""~~ Submit in Duplicate r West McArthur Unit#5 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 2,400 psi.) 3: Install2-1/8" BPV in the tubing hanger and nipple down 3-1/2" production tree. 4. Nipple up 11", 3M riser and 11", 3M BOP stack. Test BOP's to 3,000 psi. i 5. Rig up Ar~VS Ring #1 over well. Pull BPV. ~__:_:' 6. Unseat tubing hanger and release 2-7/8" tubing at 5-22 Snap-Release assembly above packer. 7. POOH with tubing and lay down for NORM testing and disposal. 8. M/U packer mill and mud motor on workstring and RIH. Mill packer until slips release. POH. 9. RIH with packer picker on workstring. Catch packer and POH. 10. RIH w/ 5-1/2" casing scraper to 13,500'. CBU and POH. 11. R/U wireline, make gauge rig /junk basket run to PBTD. POH. 12. M/U 6-1/8", 6 SPF perforating guns, RIH and perforate the following intervals: 13,485' -13,500' 13,506' -13,512' 13,566' -13,579' 13. POH, P/U new completion assembly and RIH. 14. Land tubing with packer at +13,450' and set packer. 15. Set BPV and N/D BOPE and riser. 16. N/U and test 3-1/8" production tree. 17. Pull BPV and turn well over to production. WMRU #5 Current Completion 20" 133#, L-80 BTC @103' MD, 103' TVD 13 3/8" 68#, L-80 BTC @ 2204' MD, 2151' TVD 9 5/8" 47#, L-80 BTC @ 6638' MD, 5011' TVC 7-5/8" 29.7#, L-80 STL @ 12,858' MD, 8870' T\ 5-1/2" 15.5#, L-80 Hyd 51 _ TOL @ 6,390' MD TOL @ 12,695' MD Packer @ 13,469' MD Tbg Tail @ 13,469' MD Perforations: 13,524'-14,180' MD .,443' MD, 9,800' TVD TD 14,450' MD, 9,835' 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-li, it's official!!! FYI. PACIFIC ENERGY RESOURCES LTD. 111 West Ocean Blvd., Suite 1240 Long Beach, California 90802 Telephone: (562) 628-1526; Fax: (562) 628-1536 Files for Chapter 11 to Facilitate a Restructuring \5~ -0~~~ 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. David Hall 310 K. Street, Suite 700 Alaska Operations Manager Anchorage, AK 99507 Main: 907-868-2133 Office: 907-258-8600 Cell: 907-317-8239 Fax: 907-258-8601 dmhall(a~pacenerQV.com www.pacenerav.com ~ ~ o ~ SARAN PAL/N, GOVERNOR C~~S~jRQ ~Q C ~DSI~ 333 W 7th AVENUE, SUITE 100 -7 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 ~ ®t,~ Anchorage AK 99501 ' Q` ..-'`1, Re: W. McArthur River, W. McArthur River Unit #5 Sundry Number: 308-469 Dear Mr. Hall: -~~~.~~ r. ~ f, 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, ~. L ~-'~ Cathy P. Foerster Commissioner l~ DATED this z- day of February, 2009 Encl. R STATE OF ALASKA DEC 2 3 2008 ALA OIL AND GAS CONSERVATION COM ION /f,_~i y~ APPLICATION FOR SUNDRY APPRO~(~i 8 Gas Cons. Cammiss~an 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ ~, ,Operational shutdown ^ Perforate Q Other ^ Alter casing ^ Repair well [d~~~ tJ~ Plug Perforations ^ Stimulate ^ Time Extension ^ ~~ W~'` Perforate New Pool ^ Re-enter Suspended Well ^ Change approved program ^ Pull Tubing 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Pacific Energy Resources Ltd Development ^ ~ Exploratory ^ 198-047 3. Address: Stratigraphic ^ Service ^ 6. API Number: 310 K St., Suite 700, Anchorage, AK 99501 50-133-20486-0000 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 #5 ' 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 TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14,450' 9,835' 14,317' 9,721' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 103' 20" 103' 103' N/A N/A Surface 2,204' 13-3/8" 2,204' 2,151' 5,020 psi 2,260 psi Intermediate 6,638' 9-5/8" 6,638' 5,011' 6,870 psi 4,750 psi Intermediate Liner 6,468' 7-5/8" 12,858' 8,870' 6,890 psi 4,790 psi Production Liner 1,748' 5-1/2" 14,443' 9,800' 7,740 psi 6,280 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13,524' -14,180' 9,299' - 9,665' 2-7/8" L-80 13,469' Packers and SSSV Type: Packers and SSSV MD (ft): Pkr: Baker 4530 'F', No SSSV Pkr at 13,469' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^~ Exploratory ^ Development 0 ~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 1/5/2008 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 Signature ,n ~, Phone Date "~~ r~ J~~,, 868-2133 /r~ a v~ a -. <:;, d ~~' COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Inte rity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ g ~ ~ Other: J~ ®©~ S l ~©~ ~S~ Subsequent Form Rewired: ~O~` 1 ~ Z , ~ APPROVED BY Approved by: , COMMISSIONER THE COMMISSION Date: - /'~';3 •~ Form 10-403 Revised 06/20 ~ ~ s ti ; -~ j,,,` Submit in Duplicate 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 #5 Pull-Replace Tubing operations Dear Mr. Dan Seamount, REDEIVED ~E~ 2 3 2008 Alaska Oil & ~ ~ ~ ~ ~ommis~ The West McArthur River Unit # 5 is shut in 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, ~ t `=~---~` _.~ 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. ~ t~~, ~ j . ~~~ APP ~:c s ~ ~~~~S~o r~~~E ~--~ ~ j ~,~ ~~~ , CaS4G~ U t\ ~-~ ~ 3~Cs~t\ ~c `f• LRG'I~SCc ~C.~=~1C3~~\~~~ ~1~ i3~3~1\~I~CV S ~i`;~-mac,, ~ ~~ ~ ~ ~OpC..; ~~ ~ i ~~ P~~c-ate ~ ~-~ ~`~~~.~~1 page t at L • • IVfaunder, 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 [mailto:bill@fairweather.com] Sent: Wednesday, January 21, 2009 8:23 AM To: Maunder, Thomas E (DOA) Cc: David Hall; Natasha Sachivichik Subject: RE: WMRU #S and #6 Tubing Changeouts Tom, I just spoke with a representative at Cudd. The spread on their hydraulic unit that was used on King Saimon Platform is all Cudd's. The choke and kill connections are all now flanged and they have a remote actuating panel for the BOPS. ft 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 na , longer apply. Thanks and regards; ~GGG ~P.~f~L4de 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 wiH await your next message. If the equipment "spread" is essentiaNy the same that was used on King, I dorrt foresee there being a problem. I don't have the information as to what equipment is Cudd's and what is UnocaUChevron'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 . gage ~ of z Subject: RE: WMRU #5 and ,#6 Tubing Changeouts Ta~'r~, Sorry I .;aven't responded on this earlier. I've been wanking on getting ans}Ners from Cudd on any modifications on theirs hydraulic unit since we East 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 1 hear back from him. Pacific Energy requests that the Commission continue the review and approval process for the two workovers. The tubing patch wank performed to date has been unsuccessful and the plan forward is to bring the Cudd hydraulic unit across the Inlet 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, ~~ ~~ 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: 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 #5 • 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 the following intervals 13,485'-13,500' 13,506"-13,512' 13,566'-13,579' 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. • • VVMRU #5 Current Completion 20" 133#, L-80 BTC @103' MD, 103' TVD M ;;; 13 3/8" 68#, L-80 BTC L @ 2204' MD, 2151' TVD 9 5/8" 47#, L-80 BTC @ 6638' MD, 5011' TVC 7-5/8" 29.7#, L-80 STL @ 12,858' MD, 8870' T\ 5-1 /2" 15.5#, L-80 Hyd 5" TOL @ 6,390' MD TOL @ 12,695' MD Packer @ 13,469' MD Tbg Tail @ 13,469' MD Perforations: 13,524'-14,180' MD ,443' MD, 9,800' TVD TD 14,450' MD, 9,835' TVD L I • VVMRU #5 Proposed Completion 20" 133#, L-80 BTC @103' MD, 103' TVD 13 3/8" 68#, L-80 BTC @ 2204' MD, 2151' TVD 9 5/8" 47#, L-80 BTC @ 6638' MD, 5011' TVC 7-5/8" 29.7#, L-80 STL @ 12,858' MD, 8870' T\ 5-1/2" 15.5#, L-80 Hyd 5'. . TOL @ 6,390' MD TOL @ 12,695' MD Packer @ 13,469' MD Tbg Tail @ 13,469' MD :rforations: ,485' - 13,500' MD ,506' - 13,512' MD ,566' - 13,579' MD ,524' - 14,180' MD 443' MD. 9.800' TVD TD 14,450' MD, 9,835' TVD • C D~ ~~~J 340k Jack shut lift cap340,000 sip c~:l~oooo Rotary cap: 9,70011/ll~s 11" Bore ;ific Energy WMRU#5 ~Idd Pnesslr~e COrltr+d, Inc. ~~~oe~d I~gt~ Illustration Nithat Fig on Location December 2008 3~IOI( ..lack Unit ~„ sni>b urut & V~kxk Ba~et - '~~oas) 130.5' Work WiiYbw ©evation 653.60" (54.46) 29' 23.5' 4" Flowline to Md with (',ac T l#ertr~r Xr Flc 45.2" 55.8" 23.5' 33.5' 24" ~~~~ ~~P( Swivel Spoo113-5/8" SM Drilling Spool 13-5/8" SM Anriular BOP, 13-5/8" SM i-1/2"Pipe Rain 13-5/8" SM Blind/ 5'l~ar Ram,13-5/S' SM Flow(7ross, 11" SM 3-1/2"Pipe Ram, 13-5/8" SM • • ~D~ ~=~-1 340k Jack Unit Lift Cap:34Q000 Snub Cap:170,000 Rotary Cap: 9,700 ft/Ibs 11" Bore Standpipe -~ 288" Snub Unit & Work B et > ~i`~i® X3.88') 130.8" Work Window 24" 23.5" 4" Flow Line o ud Pits low Meter 45.2" 55.8" 23.5" Blow Down Line k 3 k_2 k-1 33.8" ~ Kill Line ump ~ k~ . e.~_._:r_ra, Mud/Gas Separator 340k Jack Unit 1318" 5M BOP Stack Swivel Spool 13-5/8" 5M 2" 1 gQ2 Weco Fill Line Drilling Spool 13-5/8" SM J Annular BOP, 13-5/8" 5M 3-1/2"Pipe Ram, 13-5/8" SM Blind/ Shear Ram, 13-5/8" SM Flow Cross, 11" SM o-t o-z 3-1/2"Pipe Ram, 13-5/8" SM Choke Line o-3 Blow Down ine p Deck ~1. 13-5/8" 5M ~~ ~ 5 ~ IOMChake '~ ~~ ~' l>~fdd Choke Line 7' Spool, 13-5/8" SM ~ 84' ~ ``~ ~ 192.7" (16.06') o ~ '~ c-8 c o-9 o-5 10' Spool, 13-5/8" SM -a 120" -- -- - - ~ D,.s~,..... Tl....l. -. - - - n_u_.Y T__1 - --. Pacific Energy WMRU#5 Proposed Rigup Illustration Without Rig on Location December 2008 Well Head rd~~; t ar r AAa~nder, Th®rnas ~ (BOA) _ _ _ Frorn: Bill Penrose [bill@fainnreather.comj Sent: Wednesday, December 24, 2008 8:50 AM To: Maunder, Thomas E (DOA) Gc: Regg, James B (DOA); David Hall; Natasha Sachivichik Subject: RE: WMcRU #5 (198-047) "Toni, I'll take the liberty of answering your questions and copy everybody concerned. 1. Yau're correct, the WMRU tubing patch attempt was not successful. We should have the 404 to you today or Monday at the latest. '?. There is an I..LC valve in the well. We have a detailed completion schematic, but much of it isn`t Shawn on the overall well schematic. We'll rnerge the two so the welt schematic has all the jewelry shown on it. 3. The static BHi~ is 2,450 psi. 4. The Cudd unit will be configured exactly as it was an King Salmon Platform from which was just demobed. ~. For a workover fluid, we'll use produced water or brine with a sufficiently depressed crystallizaton point to remain liquid downhole and near the surface under the expected Cook inlet ambient temperatures. When circulation is to be stepped far any significant amount of tune, the lines will either be blown down or flusf7ed with diesel. We may also depend to a small extent an insulation and heaters --we're still working this out. Regards, ~~ ~~ Vice President /Drilling Manager Fairweather E&P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 907-25Fi-3<~46 From: Maunder, Thomas E (DOA) [maitto:tom.maunder@alaska.gov] Sent: Tuesday, December 23, 2008 1:33 PM To: David Hall; Bill Penrose Cc: Regg, James B (DOA) Subject: WMcRU #5 (198-047) David, I am reviewing the sundry to workover this well. A couple of questions ... 1. I presume the attempt to patch the tubing was not successful? 1 know the work may have only been recently attempted, but the 404 report should be submitted for anything done under the prior sundry. 2. In the request for waiver, it is mentioned that a LLC valve is in the well. I don't find anything in the documents you submitted or the file indicating that an LLC valve is present in the well. Could you provide additional detail? 3. What is the estimated BHP of the well? 4. Is the equipment planned to be employed, especially the choke and kill lines, essentially the same as was employed recently on King Salmon? 5. How does Pacific plan to prevent the workover fluid in particular and the equipment in general from freezing? I don't have Ms. Sachivichik's address, so I have forwarded this to Mr. Penrose. Thanks in advance, Tom Maunder, PE AOGCC 1 Zi24i2oog r~a~c~ i r~- e t~B~~irn~~>~~ ~~~~~s ~ ~r~~~.~ ___ _ __ Frc~u~~ Mau~~der, T~orrsas E IA) Septa Wednesday, December 24, 20081 ~ .29 Ali T®~ `!Bill Renrose5 Cc: iVatasha Sachivichik, David I•-lall Se~b]~t: RE: WMRU #5 8~ #6 Tubing Change-puts Thar~k~ Bill. ~Ne 4vill talk or~~ the sd}r~dr~e~ i~~t, hie r~~w yeas. Torn. __ ~roaae: 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, I 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 wi(I 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. ° Have a Merry Christmas and we can resume efforts on this when everyone is back in the saddle. Regards, ~e Vice President /Drilling Manager Fairweather E8~P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 907-258-3446 12/24/2008 • • ~y ~ ~"~ o SARAH PALIN, GOVERNOR ~.~ L'~14A17~ OII/ ~ ~ 333 W. 7th AVENUE, SUITE 100 CO1~S1r'iRQA'1`IO1~T COMI~IISSIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Hall Production Manager 1 ~,, Pacific Energy Resources Ltd (~ ~ d "l 310 K St Ste 700 `~, Anchorage AK 99501 Re: W. McArthur River Field and Oil Pool, W. McArthur River Unit #5 Sundry Number: 308-428 Dear Mr. Hall: S.D I..r:1~,+~4~i:-~~ lr4~t~-; v V ~ld~V 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 Conunission 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, h~ Daniel T, Seamount, Jr. Chair DATED thisZ day of December, 2008 Encl. ~.~, 4 STATE OF ALASKA t,Z ~ A OIL AND GAS CONSERVATION COM~SION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 A.(g~~;';:: 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ Weiver ^ 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 ^ 198-047 3. Address: Stratigraphic ^ Service ^ 6. API Number; 310 K St., Suite 700, Anchorage, AK 99501 50-133-20486-0000 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 #5 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 ND (ft): Plugs (measured): Junk (measured): 14,450' 9,835' 14,317' 9,721' N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 103' 20" 103' 103' N/A N/A Surface 2,204' 13-3/8" 2,204' 2,151' 5,020 psi 2,260 psi Intermediate 6,638' 9-5/8" 6,638' 5,011' 6,870 psi 4,750 psi Intermediate Liner 6,468' 7-5/8" 12,858' 8,870' 6,890 psi 4,790 psi Production Liner 1,748' 5-1/2" 14,443' 9,800' 7,740 psi 6,280 psi Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13,524' - 14,180' 9,299' - 9,665' 2-7/8" L-80 13,469' Packers and SSSV Type: Packers and SSSV MD (ft): Pkr: Baker 4530 'F', No SSSV Pkr at 13,469' 13. Attachments: Description Summary of Proposal Q 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: 11/23/2008 Oil ^~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: ~! Date: 11/22/2008 WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: T. Maunder / J. Norman 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Hall 868-2133 Printed Name Title r David Hall ~ b Production Manager Signature Phone Date ~Zr' 868-2133 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: a Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: ~~~ APPROVED BY Approved by' COMMISSIONER THE COMMISSION Date: l L /~ 0 ' ~~ 1 N ~~ Form 10-403 Revised 06/2006 `.r ~ Submit in Duplicate • • 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 November 24, 2008 Mr. Dan Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re : WMRU #5 Tubing Repair PTD No. 198-047 Dear Mr. Seamount, ~-..~. town ~,. .. k'Z 4 ~.. f Pacific Energy Resources hereby submits an Application for Sundry Approval to repair the tubing in the West McArthur River Unit #5 by installing a tubing patch across a hole located via ~~p spinner and caliper diagnostic work. ~.ti Since we already had the wireline crew, wireline unit, Pacific Energy supervision and a tubing patch on location when the diagnostic work located the tubing hole, we re uq, est`d and received ve_rb~al.,~ermission to perform the repair work immediately. This Sundry Application fol oT ws p on the verbal approval. Attached please find a Form 10-403, a summary operations procedure and a current wellbore schematic 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 Pacific Energy Resources West McArthur River Unit #5 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 3,693'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. 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. • n `1VMRU #5 Completion .~ ~, ti ;;~~a sti 20" 133#, L-80 BTC @103' MD, 103' TVD -~~' 13 3/8" 68#, L-80 BTC 4 @ 2204' MD, 2151' TVD 9 5/8" 47#, L-80 BTC @ 6638' MD, 5011' TVC 7-5/8" 29.7#, L-80 STL @ 12,858' MD, 8870' T\ 5-1/2" 15.5#, L-80 Hyd 51 TOL @ 6,390' MD TOL @ 12,695' MD Packer @ 13,469' MD Tbg Tail @ 13,469' MD Perforations 13,524'-14,180' MD 9,299'-9,665' TVD ,443' MD, 9,800' TVD TD 14,450' MD, 9,835' TVD Page 1 of 1 ~ ~ Maunder, Thomas E (DOAj From; Maunder, Thomas E (DOA) Sent: Saturday, November 22, 2008 8:55 PM To: Bill Penrose Subject: RE: Pacific Energy WMRU #5 t ~~ _ ©`t Bill, ~1. Sorry to be delayed. I have spoken with Commissioner Norman apprising him of the request and he has. authorized me to communicate his oral approval for Pacific Energy to proceed with the tubing patch in WMRU #5 as proposed in your message. Call or message with any questions. Tom Maunder, PE AOGCC From: Bill Penrose [mailto:bill@fairweather.com] Sent: Sat 11/22/2008 5:02 PM To: Maunder, Thomas E (DOA) Subject: Pacific Energy WMRU #5 Tom, This is to follow upon our earlier telephone conversation. David Hall is out-of--state and asked me to interface with you on this as his ability to communicate is limited. Pacific Energy's Hemlock oil producer, which normally produces 400 BOPD net oil on jet pump (with 65% water cut and 235 GOR), suffered a sudden drop in production late yesterday. They spent last night and today running diagnostics involving testing the tree (which is in good condition) and the surface jet pumping equipment (also good) and running spinner surveys and a tubing caliper. They've found a hole in the 2-7/8" tubing at 3,693'MD which is severely affecting the efficiency of the jet pump. Pacific Energy requests permission to run a tubing patch across the hole immediately (they have the people, tubing patch and wireline unit on location at present) and follow up with the 10-403 as soon as possible. Additional information that may assist in your consideration is: The well will not flow unassisted. There is no SSSV in the well to hamper operations. The well (when being jet pumped) produces from the Hemlock at 13,000'MD, 10,000'TVD. The hole appears to be in a tube body, not a connection. The caliper indicated the rest of the tubing is in good condition (i.e. this doesn't appear to be a harbinger of a more widespread problem in the well). The wireline unit will use apressure-tested lubricator when performing the tubing patch operation. As soon as the Commission makes a decision on this request, please drop a quick note via return a-mail. Thanks and regards, Bill Penrose 1 vaaiaaos Well ComplianC eport File on Left side of folder 198-047-0 MD 14450 W MCARTH~~ER "5 ........................ 50- 133-20486-00 FORCENERGY TVD 09835 ~rff/~letion Date: '~1/98 Completed Status: 1-OIL Current: T Name Interval T 8621 1 Daily Well Ops~/2 ~/q~" 57 ~/~//? ~ Was the well cored? yes~ Comments: Sent Received T/C/D SCHLUM DITE/SDT/LDT/CNL OH 8/25/98 8/25/98 Samples Required? yes ~_______..~And Recei-ved~. ~ao~_ Are Dry Ditch Analysis Description Received? yes no Sam~ Monday, May 01,2000 Page 1 of 1 Forcenergy Inc 310 K Street, Suite 700 Anchorage, AJaska 99501 Phone: (907) 258-8600 Fax: (907) 258-8601 DATA TRANSMITTAL Date: August 25, 1998 ITo: Lod Taylor AOGCC 3001 Porcupine Drive A,x~c~e, ~ ~95o~ Phone: (907) 279-1433 ext. 225 FAX: 276-7542 From: Unda Staff Forcener~y Inc. 310 K Street, Suite 700 Anchora~le, AK 99501 Phone: (907) 258 - 8600 ext"168 FAX: (907) 258 - 8601 TRANSMITTAL DESCRIPTION Top Log Bottom Log Permit # Well Name Q.ty Log Date Description Run Interval Interval 98-0047 W. Mc, Arthur River Unit ~k5 I 5115/98 Open Hole LIS Tape: One 3,917' 14,251' APl f,50-133-20486-00 DITE/SDT/LDT/CNL Field tape, 1600 BPI 98-0047 W. Mc, aulhur River Unit ~5 I 5/15/98 LIS Tape Verification Listing APl #50-133-20486.00 Please sign ~owledge receipt. JReceived By: Returned to For(energy Accepted By: Date !998 A~chomge Page 1 of 1 . : ~ Modif~d:8~5/98 Tranm'nittai to A~.xts ~ Preoara4:2/19/98 Forcer, rgy Inc June 9, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Well Completion Report and Log (Form 10-407) West McArthur River Unit//5 Enclosed is Forcenergy's Well Completion Report and Log for the West McArthur River Unit//5 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. HEADQUARTERS Forcenergy Center 2730 SW 3rd Avenue Suite 800 ~A;,~r~; r-I~r;~,~ QQt OCI_OOQ7 TELEPHONE 305/856-8500 FAX REGIONAL OFFICE 310 K Street Suite 700 Annhnrnnn AIn.~kn .q.qRN1 TELEPHONE 907/258-8600 FAX ~nT/2RR-RRN1 STATE OF ALASKA ALASKA Oa:.~-AND GAS CONSERVATION COi~iMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG -- - 1. St~ius of Well ' - Class~cation of Service Well OIL: X GAS: SUSPENDED ABANDONED: SERVICE: 2. N~"e of Operator Forcer~ergy Inc. --' 7. Permit Number 98-47 ,. 3. Address 310 K Street, Suite 700 8. APl N~mber Anchorage, Alaska 99501 .......... ~. ............ 50-133.20486 4. Locefl~3n ;3f well at surface ] C,,.~,~'Lr.'.'flUt'~ i 9. 0nit or Lease Name 2066' FSL, 3336' FEL, S16, T08N, R14W, SM i ~,'-",T~ .,~r"~i · ~ , ~ West McArthur River Unit At TOp Produ(~lng Interval ~, '~-- -l'~"'~l~ i 10.'Well Number 3779' FSL, 2728' FEL, S10, T08N, R14W, SM ~ ..... V~-[[ ~! Ei'.~ ~:3~'~ ~ ili~rtl~ tI~.~~ ! NO. 5 4347' FSL, 2262' FEL, S10, T08N, RI4W, SM We~t Foreland Field 5. Elevation in fe~t'(Indlcate.KBi DF, etc.i' ' ' I 6. Lease l~'e's'ignatlon and Serlal"No. West Foreland Pool 163 KBI ADL 359112 12. Dat~ ~udded la. ~ai~'l.D. ~eached '" 14. Date Comp, Susp. or ~and. 15. Water Depth, if off'shorn 18. No. of Comp~e~ons 3/7/98 4/25/98 5/11/98 n/a feet MSL 1 14,450' MD / 9,835' TVC n/a ~ Yes: x No:! n/a feet MDI n/a 22. Type Electri(~ or Other Logs Run ............ Quad Combo / SHDT / R.S..T / CBL / CET / RFT (would not pass through 6 3/4" hole,!, , , 23. CASING, LINER AND CEMENTING RECORD ...... . .. SETTING DEPTH MD CASING SIZE WT, PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED , ..... . . 20" 133# K-55 Surf. 103' driven n/a None . , 13 318" 68# L-80 Surf. 2,204' 17 1/2" 2808 cuff None .... ., 9 5/8" 47# L-80, ,. Surf. ,, .,,6,,638' 12 1/4" 1075 cuft None ,, ., 7 5/8" 29.7 # L-80 6,390' 12,858' 8 '!/2' 172 cu ~t None ,, , 5 1/2" 15.5 # L-80 12.,758,', 14,443' 6 3/4" 532 cu ~t None 24. perforations open to Production (MD+TVD of Top and Boffom and 25. ~'UBING RECORD interval, size and number) .... sIzE DEPTH SET (MD) PA~KER SET (MD) 13,538' to 13,524' 3 3/8" 6 spt TCP .... 2 7/8" 13,469' 13,469' 13,619' to 13,592' 13,633' to 13,624' 26. ACID. FRACTURE, CEMENT sQuEEZE, ETC. .,., 13,708' to 13,648' DEPTH INTERVAL (M,D) AMOUNT & KIND OF MATERIAL USED 13,738' to 13,728' nla 13,930' to 13,766' ' .... 14,008' to 13,942' .. ., 14,114' to 14,090' 14,180' to 14,126' ,. . ,.,,, , , 27. PRODUCTION TEST Date First Production ..... I Method of Operation (Flowing, gas II~"etc.) "' 5/21/98~ Hydraulic jet pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF W/{,TER-BBL C'HOKE SIZE '1 GAS-OIL RAT'IO 5/21/98 24 TEST PERIOD --> 2587 608 17 n/aI Initial Estimate 235 · . · ... , . . Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE => 28. ' ..... CORE ~ATA "~'ief ~lescriptt'on of lithology, porosity, fractures, apparent dips and presence (~f ~1i, gas or water, Submit core chips. No coring was done. ~:- .~ .,. ~., ~. ..... . ~.~ Hemlock formation consisting of interbedded sands and conglomerates. Form 10407 Rev, 7-1 CONTINUED ON REVERSE SID~ 0~ & Ga~C0~s. Cl~j~t~t in duplicate [ 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Hemlock Bench 1 13,460' Hemlock Bench 2 13,542' Hemlock Bench 3 13,640' Hemlock Bench 4 13,770' Hemlock Bench 5 14,040' Hemlock Bench 6 14,125' West Forelands 14,190' 31. LIST OF A'I-I-ACHMENTS Well Schematic, Final Directional Survey 32. I hereb~s~,rtify that the foregoing is true and correct to the best of my knowledge Signed ,~ ~~~"')1 Title Ddlling Manage~__ Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jec'tion, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 WMRU #5 Completion 20" 13 , L-80 BTC 13 3/8 68#, L-80 BTC~ 9 5/8" 47#, L-80 BTC ~ 7-5/8" 29.7#, L-80 STL 5-1/2" 15.5~, L-80 Hyd 511 ~. @103' MD, 103' TVD @2204' MD, 2151'TVD @6638' MD, 5011'TVD 2,858' MD, 8870' TVD 14,443' MD, 9,800' TVD Forcenergy Inc. West McArthur River Unit #5 Operations Summary February 27, 1998 Report #1 Initialized Rig-down on WMRU 4 February 28, 1998 Report #2 Rig move March 1; 1998 Report #3 Continued rig move March 2, 1998 Report #4 Commence rig-up on WMRU #5 March 3, 1998 Continued rig-up operations Report #5 March 4, 1998 Report #6 Continued rig-up operations March 5, 1998 Report #7 Drive 20" conductor to 123' RKB. March 6, 1998 Pick up BHA, prepare to spud. Report #8 March 7, 1998 Report #9 Drill 17 ½" hole to 580', POOH for mud motor and MWD. March 8, 1998 Report #10 RIH, D~rectionally drill 17 ½" hole to 1377'. March 9, 1998 Report #11 Directionally drill 17 ½" hole to 1548', Top drive failure, Directionally drill to 2099'. March 10, 1998 Report #12 Directionally drill 17 ½" hole to 2193', POOH for BHA change, RIH, Directionally drill to 2204', CBU. March 11, 1998 Report #13 Run and cement 13 3/8" 68#, casing to 2204'. March 12, 1998 Report #14 Cut and laydown 20", Nipple up 13 3/8" casing head, Nipple up 13 5/8" BOPE. March 13, 1998 Report #15 Test BOPE. - Lou Grimaldi witnessed. March 14, 1998 Report #16 Rebuild choke, test same, Lay down 17 ½" tools, PU 12 1/4" BHA, Drill float collar, cement, and shoe. March 15, 1998 Report #17 Drill to 2224', Perform leak off test to 15.5 ppg EMW, Directionally drill 12 ~A" hole to 3237'. March 16, 1998 Report #18 Directionally drill to 4441 ', POOH for bit. Forcenergy Inc. West McArthur River Unit #5 Operations Summary March 17, 1998 Report #19 PU new BHA, Directionally drill to 4951 ', well flowing, CBU. March 18, 1998 Report #20 Weight up to 10.2 ppg, Drill 12 '/4" hole to 4965', Circulate out sand, Circulate and short trip. March 19, 1998 Report #21 Directionally drill 12 ¼" hole to 6514'. March 20, 1998 Report #22 Directionally drill to 6537', CBU, Weight up to 10.3 ppg, Circulate, POOH. March 21, 1998 Report #23 Change BHA, Wash and Ream to 6400'. March 22, 1998 Report #24 Wash to 6537', Directionally drill 12 1/4" hole to 6643', CBU twice, Short trip to 4654', CBU, Short trip to 4846', POOH. March 23, 1998 Report #25 Change BOP rams, Rig up 9 5/8" casing equipment, Run 9 5/8" casing to 6635'. March 24, 1998 Report #26 Cement 9 5/8" casing, ND BOPE stack, Install 9 5/8" casing slips, Cut 9 5/8" casing, Install 11" tubing spool, Install DSA, Install 13 5/8" BOP stack. March 25, 1998 Report #27 Change out bales, Change out BOP rams, Lay down 12 ¼" BHA, PU 8 '/2" BHA, RIH. March 26, 1998 Report #28 Drill cement, prep to change over to OBM. March 27, 1998 Report #29 Test 9 5/8" casing, Drill 20' of new 8 ½" hole, Perform leak off test to 14.5 ppg EMW, POOH, Change BHA. March 28, 1998 Report #30 Directionally drill 8 ½" hole to 7188'. March 29, 1998 Report #31 Directionally drill 8 ½" hole to 7633', Short trip, Directionally drill to 7918'. March 30, 1998 Report #32 Directionally drill 8 ½" hole to 8755', Short trip. March 31, 1998 Report #33 Continue short trip, Directionally drill 8 ½" hole to 9400' Forcenergy Inc. West McArthur River Unit #5 Operations Summary April 1, 1998 Report #34 Directionally drill 8 ½" hole to 9734', Short trip to shoe, Directionally drill to 9920'. April 2,'1998 Report #35 Directionally drill 8 ~A" hole to 10309', Short trip, Dkectionally drill to 10416'. April 3~ 1998 Report #36 Directionally drill 8 'A" hole to 10812', CBU, POOH. April 4, 1998 Report #37 Test BOPE, Change BHA, RIH, Directionally drill 8 ½" hole to 10940'. April 5~ 1998 Report #38 Directionally drill 8 'A" hole to 11680'. April 6~ 1998 Report #39 Directionally drill 8 ½" hole to 12125' April 7, 1998 Report #40 Directionally drill 8 'A" hole to 12467'. April 8,.1998 Report #41 Directionally drill 8 ½" hole to 12552', POOH, Change BHA, RIH, Directionally drill 8 ½" hole to 12580'. April 9, 1998 Report #42 Directionally drill 8 ~/~" hole to 12720', POOH, Change BHA. April 10~ 1998 Report #43 R_IH, Directionally drill 8 ½" hole to 12858'. April 11, 1998 Report #44 Short trip to clean hole for 7 5/8" casing. April 12, 1998 Report #45 POOH, Rig up to run 7 5/8" casing, RIH with 7 5/8" liner to 12858' on drill pipe. April 13~ 1998 Report #46 Lay down 8 ½" BHA, RIH with 7 5/8" liner to 12858' MD. April 14, 1998 Report #47 Pump 30.7 bbl of 15.8 ppg cement. Set liner hanger. Set liner top packer, Circulate, POOH with running tool. Pull wear ring. April 15~ 1998 Report #48 Test BOPs. Make up 6 ¼" BI-IA. Test casing to 3000 psi. No pass. Retest to 1900 psL Passed. April 16, 1998 Report #49 Clean out cement and 4' of new hole. Perform leak off test. Drill 6 ~" hole to 12857'. Perform leak off test to 2200 psi. Drill 6 ~/4" hole to 12936'. April 17, 1998 Report #50 Directionally drill 6 3/4" hole to 13045'. POOH. Change BHA. R/H. Directionally drill 6 ¼" hole to 13085'. Forcenergy Inc. West McArthur River Unit #5 Operations Summary April 18, 1998 Report #51 Directionally drill 6 3A" hole to 13506'. April 19, 1998 Report #52 Directionally drill 6 3/4" hole to 13509'. POOH, Change BHA. RIH. Directionally drill 6 3/4" hole to 13545'. April 20, 1998 Report #53 Directionally drill 6 ¼" hole to 13600'. POOH. Change BHA, RIH. April 21, 1998 Report #54 Directionally drill 6 %" hole to 13780'. Short trip to shoe. Drill to 13811' April 22, 1998 Report #55 POOH. Test BOPE, change BHA, RIH. April 23, 1998 Report #56 Directionally drill 6 3/4" hole to 13941', short trip to shoe, drill to 13958' April 24, 1998 Report #57 Directionally drill 6 3/4" hole to 14011 ', POOH, change BHA, RIH. April 25, 1998 Report #58 Continue RIH, Directionally drill 6 3¼,, hole to 14122', short trip, drill to 14237'. April 26, 1998 Report #59 Directionally drill 6 3/4" hole to 14450' TD. Short trip to shoe, POOH. April 27, 1998 Report #60 Lay down 6 3/4" BHA, Rig up for wireline logging, Log 6 3/4" hole and 8 ½" hole with quad combo. Log 6 3/4" hole with DIT, log 6 3/4- hole with SHDT dip meter. April 28, 1998 Report #61 Log 6 3/4,, hole with RFT. RFT would not pass through hole, RIH with 6 3/4,, BHA to 14450'. April 29, 1998 Report #62 Short trip to shoe, POOH, rig up wireline, run RFT logs, RFT would not pass through hole. April 30, 1998 Report #63 RIH with 6 %" BHA, short trip to shoe, POOH. May 1, 1998 Report #64 Lay down 6 3/4" BHA, Run 5 ½" liner to 14450. Pump 95 bbls of cement. Unlatch running tool from liner. May 2, 1998 Report #65 Circulate out cement, POOH, RIH with 9 5/8" casing scraper to 7 5/8" liner top. POOH. May 3, 1998 Report #66 Lay down BHA, pick up 7 5/8" casing scraper, RIH to 5 ½" liner top, circulate. May 4, 1998 Report #67 POOH, lay down BHA, RIH with 5 ½" casing scrapper, clean out cement to 14300'. Forcener y Inc._ West McArthur River Unit #5 Operations Summary May 5, 1998 Report/t68 Clean out cement to 14317'. Test casing to 2000 psi, POOH, Run CBL and RST logs to 14322'. May 6, 1998 Report #69 Rig down wireline. RIH open ended. Change hole over to crude. May 7, 1998 Report #70 POOH, lay down workstring. Pick up 5 ½" packer and TCP guns on 2 7/8" tubing. RIH. May 8, 1998 Report #71 Continue to run in hole with completion assembly. May 9, 1998 Report #72 Set 5 ½" packer at 13469', POOH with 2 7/8" tubing workstring. Pick up jet pump cavity and seal assembly, RIH on 2 7/8" tubing. May 10, 1998 Report #73 Sting seal assembly into packer seal bore. Land tubing hanger. Nipple down BOPE. Nipple up production tree, test tree to 5000 psi, Pressure up to 3300 psi to detonate TCP guns. Shut in well, monitor and record surface pressure. May 11, 1998 Report #74 Run gauge bundle in hole on wireline. Record temperature and pressure downhole for 12 hours. POOH with gauges. RIH with standing valve on wireline. May 12, 1998 Report #75 Bundle test well to 1500 psi, tie well into production facility. Circulate power oil bottoms up twice. Drop jet pump from lubricator. Pressure up on power oil. Bring well on-line. May 13, 1998 Prep rig for rig move. Report #76 May 14, 1998 Report #77 Continue preparing rig for rig move. May 15, 1998 Report #78 Continue rigging down and prepping for rig move. May 16, 1998 Report #79 Continue prepping for rig move. Reverse out hydraulic jet pump. Assist production with slickline work. Pull standing valve with slickline. May 17, 1998 Report #80 Pump down jet pump. Begin flow test. Retrieve jet pump and standing valve. May 18, 1998 Report #81 Kill well with produced water, set back pressure valve, nipple down production tree, nipple up BOPs, test BOPs, POOH with 2 7/8" tubing. May 19, 1998 Report #81 Continue to POOH with tubing, pump cavity and seal assembly. Redress seals, RIH with seal assembly and pump cavity on 2 7/8" tubing. Enter packer and space out, land tubing hanger. Perform bundle test to 1500 psi, test good. Install back pressure valve, prep to remove BOPs. Forcenergy Inc., West McArthur River Unit #5 Operations Summary May 20, 1998 Report #82 Nipple down BOPs, Nipple up production tree and test to 5000 psi. Displace well with crude. Tie production tree to power oil and produced oil lines. May 21, 1998 Report #83 Prep rig for WMRU g4. Bring WMRU #5 on production. SURVEY REPORT Client: FORCENERGY Field: WMRU Well Name: WMRU 5 APl number: 50-13320484 Job number: 40002337 Rig: NABORS 160 County:. ANCHORAGE State: AK Spud Date: 7-Mar-98 Last survey date: 26-Apr-98 Total accepted survey 154 MD of firstsurvey: 0 FT MD of last survey:. 14450 FT Survey Calculations Calc method for positi, Minimum Curvature Calc method for DLS: Mason & Taylor Depth references Permanent datum MSL 0 FT Depth reference KB 163, FT GL above Permanent KB above Permanent 163 FT DF above Permanent 160 FT Vertical section od~lin Lati~lude (+N/S-): 0 FT Departure (+E/W-): 0 FT Latitude(+N/S-): Longitude(+E/W-): 60.78254915 degrees -151.74674268 degrees Azim from rotary table to target: 40.21 degrees Geomagnetic data Magnetic Model: BGGM 199~ Version Magnelic Date: 31-0ec-97 Magnaticfieldstrengff 1105.72 HCNT Magnetic dec (+E/W-) 21.69 degrees Magnetic Dip: 73.516 degrees MWD Survey Reference Criteria Reference G: ~ 4,1002 milliG Reference H: 1105 HCNT Reference Dip: 73.51 degrees Tolerance G: 3 milliG Tolerance-H: 6 HCNT Tolerance Dip: 0.3 degrees Correction Magnetic dec (+F_NV') 21.69 degrees Grid convergence (+E, 0 degrees Total az cerr (+FJVV-): 21.686 degrees Schlumberger ANADRILL Survey/Report I S, eq Measured Incl Azimuth Course TVD Verticat Displacement Totat atAzrn DLS Srvy Tool ! # Depth angle angle length depth section +N/S- +ENV- displacement (deg/ tool quality (fl1 (deg1 (deg) (ft) (fl) (fl) (fi) (fl) (fl) (~) t00f) ~ , ~ . I 0 0.0 0.0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP - - 2 115 0.5 17.0 115 115.00 0.46 0.48 0.15 0.50 17.00 0.43 GYR 3 241 0.0 0.0 126 241.00 0.97 1.01 0.31 1.05 17.00 0.28 GYR 4 331 0.3 309.0 90 331.00 0.96 1.13 0.15 1.14 7.81 0.28 GYR 5 420 0.0 0.0 89 420.00 0.96 1.25 0.00 1.25 0.18 0.28 GYR 6 512 0.3 315.0 92 512.00 0.97 1.39 -0.14 1.40 354.34 0.27 GYR 7 605 0.5 5.0 93 604.99 1.32 1.94 -0.25 1.96 352.77 0.42 GYP, 8 693 2.0 35.0 88 692.97 3.17 3.58 0.67 3.64 10.57 1.80 GYR 9 783 4.0 39.0 90 782.84 7.87 7.31 3.54 8.12 25.88 2.23 GYR 10 871 5.2 35.4 88 870.58 14.92 12.95 7.79 15.11 31.03 1.41 MWD 6-axis 11 993 7.0 32.0 90 991.86 27.80 23.77 14.94 28.08 32.15 1.50 GYR 12 1080 7.9 30.6 119 1078.15 38.88 32.55 21.72 39.13 33.71 1.45 MWD 6-axis 13 1176 8.8 33,9 96 1173.11 52.80 44.89 28.88 53.27 32.58 1.01 MWD 6-axJs 14 1272 10.1 34.0 96 1267.80 88.48 57.97 37.50 69.04 32.89 1,31 MWD 6-axis 15 1367 12.5 34.6 95 1360.96 86.96 73.32 47.98 87.62 33.20 2.51 MWD 6-axis 16 1463 14.6 34.2 96 1454.28 109.34 91.88 60.88 110.11 33.44 2.25 MWD 6-axis 17 1557 16.4 33.9 94 1544.85 135.34 112.71 74.75 135.25 33.55 1.88 MWD 6-axis 18 1653 18.3 35.0 96 1636.49 162.64 t38.33 90.97 163.90 33.71 2.04 MWD 6-axis 19 1749 20.1 36.4 96 1727.14 194.31 161.95 109.40 195.44 64.04 1.86 MWD 6-ax~s 20 1845 21.8 35.3 96 1816.79 228.52 189.77 129.49 229,74 34.31 1.89 MWD 6-axis 21 1941 23.3 35.2 96 1905.43 265.23 219.86 150.75 266.58 34.44 1.54 MWD 6-axis 22 2037 .25.7 35.2 98 1992.78 304.92 252,18 174.00 306.38 34.60 2.63 MWD 6-axis 23 2132 28.2 35.3 95 2077.45 347.86 287.15 199.15 349,45 34.74 2.70 MWD 6-ax~s 24 2216 28.7 35.6 84 2151.28 387.77 319.77 222.38 389.50 34.82 0.61 MWD 6-axis 25 2312 31.7 35.8 96 2234.26 435.89 358.98 250.55 437.75 34.82 3.05 MWD 6-axis Page 1 Schlumberger ANADRILL Survey/Report Seq Measured Incl Azimuth Coume 'I'VD Vertical Displacement Total at Azm DLS Srvy Tool # Depth angle angle length depth section +N/S- +E/W- displacement (deg/ tool .quality (flt , (;deg) (deg) (fi) (ft) (fl) (fi) (fl) (fi) (deg) 1000 type type 26 2411 33.9 36.6 99 2317.49 489.35 402.21 282.21 491.34 35.06 2.32 MWD 6-a)ds 27 2507 36.4 37.7 96 2396.00 544.51 446.22 315.58 546.54 35.27 2.63 MWD 6-axis 28 2603 38.9 39.2 96 2472.04 603.07 492.09 352.03 605.04 35.58 2.80 MVVD 6-axis 29 2699 41.4 39.3 96 2545.40 664.97 540,03 391.20 666,83 35.92 2.67 MVVD 6-axis 30 2795 43.9 39.9 96 2616.00 730.03 590.t4 432.66 731.75 35.25 2.57 MWD 6-axis 31 2891 46.5 39.3 96 2683.63 798.11 542.63 476.07 799.76 36.53 2.81 MVVD 6-axis 32 2987 48.9 40.3 96 2748.20 869.15 697.20 521.55 870.69 36.80 2.63 MWD 6-axis 33 3082 51.5 41.1 95 2808.98 942.15 752.54 569.16 943.53 37.10 2.77 MWD 6-axis 34 3178 50.9 41.1 96 2869.13 1016.95 808.91 618.35 1018.18 37.39 0.62 MWD 6-axis 35 3275 50.8 40.9 97 2930.37 1092.18 865.70 667.71 1093.28 37.64 0.18 MWD 6-axis 36 3371 51.7 40.9 96 2990.41 1167.07 922.31 716.74 1168.06 37.85 0,93 MWD 6-axis 37 3467 51.4 41.5 96 3050.12 1242.23 978.86 766.25 1243.11 38.05 0.62 MWD 6-axis 38 3563 51.0 41.6 96 3110.31 1317.00 1034.84 815.86 1317.77 38.25 0.37 MVVD 6-axis 39 3659 52.9 41.9 96 3169.48 1392.56 1091.23 866.20 1393.23 38.44 1.99 MWD 6-ax~s 40 3755 52.3 41.5 96 3227.80 1468.79 1146.16 916.92 1469.36 38.61 0.73 MWD 6-axis 41 3850 51.9 41.4 95 3286.20 1543.70 1204.32 966.52 1544,20 38.75 0.43 MWD 6-axis 42 3946 51.6 41.2 96 3345.67 1619.05 1260.94 1016.26 1619.49 - 38.87 ' ' 0.35 MWD 6-axis 43 4042 51.3 41.1 96 3405.49 1694.12 1317.48 1065,67 1694.52 38.97 0.25 MWD 6-axis 44 4138 51.0 40.7 95 3465.71 1768.88 1373.98 1114.62 1769.24 39.07 0.51 MWD 6-axis 45 4234 53.6 40.5 95 3524.45 1844.80 1431.63 1164.03 1845.14 39.11 2.74 MWD 6-axis 46 4327 53.4 40.0 93 3579.80 1919.54 1488.72 1212.27 1919. 86 39.16 0.57 MWD 6-axis 47 4419 53.0 39.6 92 3634.93 1993.19 1545.35 1259.30 1993.57 39.18 0.46 MWD 6-axis 48 4515 51.9 39.5 95 3639.39 2069.32 1604.05 1307.85 2069.65 39.19 1.11 MWD 6-axis 49 4611 50.8 39.5 95 3753.34 2144.29 1681.91 1355.54 2144.62 39.20 1.24 MWD 6-axis 50 4707 50.6 40.0 96 3814.16 2218.57 1719.01 1403.93 2218.90 39.22 0.43 MWD 6-axis 51 4803 51.9 39.3 96 3874.26 2293.43 1776.66 1450.80 2293.76 39.23 1.42 MWD 6-axis 52 4899 51.1 39.5 96 3934.05 2368.52 1834.69 1498.47 2368.80 39.24 0.84 MWD 6-axis 53 4995 49.8 40.3 96 3995.20 2442.52 1891,48 1545.93 2442.85 39.26 1.50 MWD 6-axis 54 5091 50.9 40.0 96 4056.50 2516.40 1947.94 1593.57 2516.73 39.29 1.15 MWD 6-axis 55 5187 51.2 39.8 96 4116.88 2591.04 2005.20 1641.44 2591.36 39.30 0.39 MWD 6-axis 56 5282 51.2 39.6 95 4176.43 2665.05 2062.14 1688.77 2665.37 39.3 1 0.17 MWD 6-axis 57 5378 50.7 39.3 96 4235.98 2739.54 2119.67 1736.00 2739.87 39.32 0.57 MWD 6-axis 58 5474 51.4 40.1 96 4297.38 2814.50 2177.09 1783.73 2814.50 39.33 1.01 MWD 6-axis 59 5570 51.0 40.0 96 4357.52 2888.98 2234.36 1831.87 2889.31 39.35 0.42 MWD 6-axis 60 5665 52.3 40.2 95 4416.45 2963.49 2291.35 t879.87 2963.82 39.37 1.40 MWD 6-axis 61 5761 51.9 40.3 96 4475.39 30,39.27 2349.18 . 1928.83 3039.58 39.39 0.42 MWD 6-axis 62 5857 51.3 40.0 96 4535.00 3114.52 2406.70 1977.35 3114.82 39.41 0,68 MWD 6-ax~s 63 5953 50.9 39.7 96 4595.29 3189.22 2464.05 2025.27 3189.53 39.42 0.51 MWD 6-axis 64 6048 52.4 39.9 95 4654.26 3263.70 2521.27 2072.89 3254.00 39.44 1.59 MWD 6-axis 65 6144 52.3 40.0 96 4712.92 3,339.69 2579.53 2121.69 3339.99 39.44 0.12 MWD 6-axis 66 6240 52.2 39.9 96 4771.73 3415.58 2637.70 2170.47 3415.87 39.45 0.17 MWD 6-axis 67 6336 52.3 39.7 96 4830.58 3491.42 2695.98 2218.97 3491.72 39.46 0.20 MWD 6-axis 68 6432 52.2 39.5 96 4889.34 3567.32 2754.47 2267.30 3567.53 39.46 0.17 MVVD 6-axis 69 6528 53.0 40.1 96 4947.64 3643.59 2813.06 2316.18 3643.~ 39.47 0.91 MWD 6-axis 70 6567 53.6 39.7 39 4970.95 3674.85 2837.04 2336.23 3675.16 39.47 1.81 MWD 6-axis 71 6612 53.4 39.5 45 4997.72 3711.02 2864.92 2359.29 3711.33 39.47 0.57 MWD 6-axis 72 6708 53.5 39.2 96 5054.90 3788.13 2924.55 2408.98 3788.45 39.47 0.27 MWD 6-axis 73 6804 64.3 40.6 96 5111.45 3865.70 2984.06 2457.95 3866,02 39.48 1.47 MWD 6-axis 74 6899 55.1 40.7 95 5166.35 3943.23 3042.88 2508.45 3943.53 39.50 0.77 MWD 6-axis 75 6994 52.9 39.0 95 5222.21 4020.06 3101.85 2557.70 4020.30 39.50 2.69 MWD 6-axis 76 7089 52.9 38.9 95 5279.52 4095,81 3160.78 2605.33 4096.13 39.50 0.09 MWD 6-axis 77 7185 51.3 41.5 96 5,338.49 4171.55 3218.64 2654.20 4171.87 39.51 2.69 MWD 6-axis 78 7280 51.6 41.9 95 5397.58 4245.84 3274.12 2703.63 4246.12 39.55 0.44 MWD 6-axfs 79 7377 52.7 41.6 97 5457.23 4322.37 3331.25 2754.62 4322.63 39.59 1.11 MWD 6-axis 80 7473 49.9 42.3 96 5517.25 4397.25 3386.96 2804.69 4397.78 39.63 2.88 MWD 6-axis 81 7568 49.2 42.8 95 5578.84 4469.52 3440.25 28,53.60 4469.71 39.67 0.85 MWD 6-axis 82 7663 49.8 42.8 95 5640.50 4541.71 3493.28 2902.70 4541.88 39.72 0.63 MWD 6-axis 83 7758 50.5 43.2 95 5701.33 4514.6 3546.64 2952.47 4514.73 39.78 - 0.81 MWD 6-axis Page 2 Schlumberger ANADRILL Survey Report Seq Measured Incl Azimuth Course TVD Vertical Displacement Total at Azm DLS Srvy Tool # Depth angle angle length depth section +N/S- +E/W- displacement (deg/ tool quality Cfi/ Cdev} (deg) Cfi;) (fi) ' (fi) (fi) Cfi) {~ff) (deg) 100~ type type 84 7854 51.0 43.0 96 5762.05 4688.86 3600.94 3003.27 4688.95 39.83 0.50 MWD 6-axis 85 7950 49.9 40.8 96 5823.20 4762.83 3656.01 3052.70 4762.92 39.86 2.11 MWD 6-axis 86 8043 50.3 40.0 93 5882.89 4834.14 3710.32 3098.92 4834.33 39.87 0.76 MWD 6-axis 87 8139 50.7 40.5 96 5943.97 4908.20 3766.84 3146.77 4982.95 39.87 0.63 MWD 6-axis 88 8235 51.4 40.5 95 6004.31 4982.87 3823.62 3195.27 4982.95 39.88 0.71 MWD 6-axis 89 8330 51.3 41.5 95 6063.62 5057.08 3879.63 3243,95 5057.15 39.90 0.82 MWD 6-axis 90 8425 51.7 41.4 95 6122.76 5131.41 3935.35 3293.17 5131.47 39~2 0.35 MVVD 6-axis 91 8522 52.1 41.1 97 6198.62 5207.72 3992.74 3343.49 5207.77 39.94 0.53 MWD 6-axis 92 8618 53.1 40.3 95 6240.95 5283.95 4050.55 3393.27 5284.01 39.95 1.17 MWD 6-axis 93 8716 53.7 40.4 98 6298.46 5362.88 4110.47 344~.17 5362.63 39.98 0.62 MWD 6-a~s 94 8812 52.7 40.1 98 6357.01 5439.41 4169.10 3493,70 54,39.46 39~96 1.05 MWD 6-axis 95 8907 51.4 38.0 95 6415.46 5514`28 4227.25 3540.94 5514.34 38.95 220 MWD 6-axis 96 9002 51.5 37.6 95 6474.66 5588.52 4285.96 3586.46 5588.59 39.92 0.36 MVVD G-axis 97 9098 52.3 37.7 96 6533.88 5664.00 4345.78 3632.63 5864.08 39.89 0.82 MWD 6-axis 98 9191 52.9 37.4 93 6590.35 5737.81 4404.36 3677.67 5737.91 39.86 0.71 MWD 6-axis 99 9287 53.1 37.2 96 6648.14 5814.37 4465.34 3724.12 5814.49 39.83 0.22 MWD 6-axis 100 9383 51.4 36.8 95 6706.93 5890.13 4525.95 3769.79 5890.29 39.79 1.75 MWD 6-axis 101 9478 52.5 38.4 95 6765.51 5964.77 4585.99 3814.35 5964~96 39.75 1.14 MWD 6-axis 102 9574 52.9 36.4 95 8823.73 6040.94 4647.43 3859.58 6041.17 39.71 0.45 MWD - 6-axis 103 9670 53.5 35.5 98 688126 6117.57 4709.64 3904.79 6117.85 39.66 0~98 MWD 6-axis 104 9766 52.8 37.0 96 6938.86 6194.19 4771.58 3950.20 6194.52 39.62 1.44 MWD 6-axis 105 9862 52.6 37.0 98 6997.07 6270.40 4832.54 3992.64 6270.77 39.59 0`25 MWD 6-axis 106 9958 52.7 38.0 98 7055.35 · 6346.53 4893.87 4041.52 6346~95 39.55 0.84 MVVD 6-axis 107 10054 52.2 38.2 96 7113.89 6422.50 4954.55 4087.47 6422.95 39.52 1.90 MWD 6-axis 108 10149 51.3 37.8 95 7172.74 6497.02 5013.31 4133.32 6497.51 39.50 0.98 MWD 6-axis 109 10245 51.2 37.7 96 7232.85 6571.80 5072,50 4179.15 6572.33 39.46 0.12 MWD 6-axis 110 10341 51.4 38.2 96 7292.90 6646.64 5131.56 4225`27 6647.20 39.47 0.45 MWD 6-axis 111 10437 50.4 37.5 98 7353.47 6721.05 5190.35 4270.97 6721.65 39.46 1.18 MWD 6-axis 112 10533 49.0 37.0 98 7415.58 6794,15 5246.63 4315.21 6794.79 39.43 1.50 MWD 6-axis 113 10629 49.6 38.5 95 7478.22 6866.77 5306.92 4358.74 6867.46 39.40 0.71 MWD 6-axis 114 10726 50.5 35.9 97 7540.55 6940.91 5366.90 4402.64 6941.67 39.35 1.65 MWD 6-axis 115 10822 50.9 35.8 96 7601.37 7014.97 5427.10 4446.13 7015.81 39.33 0.46 MWD G-axis 116 10917 51.0 38.8 95 766126 7088.62 5485.76 4490.82 7089,50 39.30 2.45 MWD 6-a)ds 117 11013 50.8 44.0 96 7721.85 7163.03 5541.59 4540.04 7153.89 39.33 4.21 MWD 6-axis 118 11109 51.1 44.1 96 7782.32 7237.42 5595.18 4591.88 7238.19 39.38 0.33 MVVD 6-axis 119 11205 50.9 43.6 98 7842.75 7311.87 5648.98 4643.50 7312.58 39.42 0.46 MWD 6-axis 120 11300 50.7 43.8 95 7902.83 7385.32 5702.18 4694.40 7385.95 39.46 0.27 MWD 6-axis 121 11396 50.2 43.6 96 7963.96 7459.21 5755.69 4745.54 7459.77 39.51 0.49 MWD 6-axis 122 11492 49.9 42.9 95 8025.59 7532.71 5809.30 4795.97 7533.22 39.54 0.66 MWD 6-axis 123 11588 50.1 43.5 96 8087.31 7606.14 5862.91 4846.31 7606.50 39.58 0.53 MWD 6-axis 124 11683 50.0 42.9 95 8146.31 7678.87 5916.00 4896.17 7679.20 39.61 0.50 MWD 6-axis 125 11779 49.4 44.2 95 8210.43 7751.93 5969.04 4946.59 7752.30 39.65 1,23 MVVD 6-axis 126 11875 51.6 44.4 98 8271.56 7825.76 6022.02 4996.28 7826.08 39.69 2.30 MWD . 6-axis 127 11971 51.8 45.2 95 8331.09 7900.83 6075.45 5051.35 7901.09 39.74 0.70 MWD 6-axis 128 12067 51.4 44.3 96 8390.73 7975.82 6128.87 5104.31 7976.03 39.79 0.86 MWD 6-axis 129 12163 51.0 44.0 98 8450.93 8050.42 6182.53 5156.40 8050.50 39.83 0.51 MWD 6-axis 130 12259 51.2 43.1 95 6511.27 8124.96 6235.55 5207.84 8125.11 39.86 0.76 MWD 6-axis 131 12355 51.5 43.6 96 8571.25 8199.80 6291.15 525929 8199~92 39.90 0.53 MWD 6-axis 132 12450 51.3 42.4 95 8630.54 8273.94 6345.44 5309.92 8274.05 39.92 1.01 MWD 6-axis 133 12481 52.2 43.0 31 8649.73 8298.26 6363.33 5326.43 8298.36 39.93 3.31 MWD 6-axis 134 12555 52.3 43.2 72 8693.81 6355.12 6404.90 5365.33 8355.20 39.95 0.26 MWD 6-axis 135 12552 52.7 41.8 97 8754.11 8433.57 6462.77 5418.38 8433.64 39.98 120 MWD 6-a)ds 135 12668 53.0 41.9 16 8763.78 8446.31 5472.27 5426.89 8446.38 39.98 2.18 MWD 6-axis 137 12897 54.5 43.2 229 8899.19 8630.82 6608.29 5551.78 8630.86 40.03 0.80 MWD 6-axis 138 12974 .56.3 43.0 77 8942.91 8694.12 6654.57 5595.08 8694.15 40.06 2.35 MWD 6-axis 139 13089 65.2 42.2 115 9007.66 8789.08 6724,53 5659.47 8789.10 40.08 1.14 MWD 6-axis 140 13164 52.9 40.3 95 9063.45 8865.94 6782.32 5710.12 8865.96 40.09 2.89 MWD 6-axis 141 13281 51.7 37.9 97 9122.77 8942.67 6841.88 5758.52 8942.69 40.09 2.32 MWD 6-axis P~e3 .Schlumberger ANADRILL Survey Report Projected survey: 154 14450 49.3 40.9 Seq Measured Incl Azimulh Course TVD Vertical Displacement Total at Azm DLS Srvy Tool # Depth angle angle length depth section +N/S- +EAN- displacement (decj/ tool quality (ill (deg) (deg~ (ft) (fi) (fi) (fi) (fi) (ft) (,deg) 1000 type type 142 13377 52.4 37.9 96 9181.81 9018.30 6901.59 5805.03 9018.33 40~.1 0.73 MWD 6-axis 143 13472 51.9 37.9 95 9240.01 9093.29 6961.36 5850.47 9093.33 40.04 0.53 MWD 6-axis 144 13572 51.3 38.2 100 9328.83 9205.28 7049.61 5919.55 9205.33 40.02 0.45 MWD 6-axis 145 13672 52.6 39.0 100 9363.85 9250.28 7084.04 5948.54 9250.33 40.02 1.44 MWD 6-axis 146 13771 55.0 39.3 99 9422.32 9330.15 7145.98 5998,98 9330~.1 40.01 2.44 MWD 6-axis 147 13861 55.1 39.3 90 9473.87 9403.91 7203.07 6045.70 9403.97 40.01 0.11 MVVD 6-axis 148 13958 53.4 39.0 97 9530.54 9482.62 7264.11 6095.40 9482.68 40.00 1.77 MWD 6-axis 149 14054 52.3 39.0 95 9588.52 9559.12 7323.58 6143.55 9559.19 39.99 1.15 MWD 6-axis 150 14155 52.4 39.3 101 955021 9639.07 7385.59 6194.04 9639.15 39.99 0.26 MWD 6-axis 151 14253 51.9 39.3 98 9710.34 9716.44 7445.47 6243.05 9716.52 39.98 0.61 MWD 6-axis 152 14349 51.0 40.0 96 9770.20 9791.49 7503.26 6292.94 9791.57 39.98 1.14 MVVD 6-axis 153 14375 50.0 40.9 26 9786.75 9811.55 7518.52 6303.95 9811.63 39.98 4.53 MWD 6-axis 75 9835.31 9868.70 7561.73 6341.38 9868.78 39.98 0.93 Projected Survey Page 4 Forcenergy Inc Apdl 17, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. Blair Wondzell Re: West McArthur River Unit #5 Mr. Wondzell t/IM COMM COMM , , RES ENG I SR ENG NRO .. SR GEOL GEOL ASST_, STAT TECH STAT TECH This is a follow-up acknowledgment to our phone conversations last night, concerning the 7 5/8" ddlling liner on our West McArthur River Unit #5 wee Your derision was to allow us to proceed with ddlling the 6 %" hole to our planned TD. Due to the lack of proof that there was cement around the shoe, two leak of tests were performed. They were both successfully taken to 2,200 psi, with the pressure holding at 2,105 psi at 10 minutes and 2,100 psi at 20 minutes. The 7 5/8" drilling liner which was run in the West McArthur River Unit # 5 was simply to allow for a short production liner. Keeping the production liner small, short allow us good rotation and redprocation dudng the cementing process. The 7 518" liner had no purpose for pressure control, simply as a mechanical block to the open hole. We appreciate the cooperation that you give us in these matters, espedally at odd hours, like this operation. Prompt action in these situations prevents unnecessary expenditures and schedule delays. If there are any questions, please contact me at 907-2588600. Paul VVhite Drilling Manager Forcenergy Inc. APR 2 ,998 H EAI~INuI~~C Date Modrrmd: 4/21/98 Date Prepared: 4/16/98 pc REGIONAL OFFICE Forcenergy Center 2730 SW 3rd Avenue Suite 800 Miami, Florida 33129-2237 TELEPHONE 305/856-8500 FAX 305/856-4300 310 K Street Suite 700 Anchorage, Alaska 99501 TELEPHONE 907/258-8600 FAX 907/258-8601 AOGCC Confidential Cover S~eet ...... OFFTEST .......... ~it ~ F~CE~GY 1~ ~ ~ST ~TH~ ~R Riq A~O~G.C.C, In~ W~ ~NE~IN~ ..... M~ We~N S.G. of G~nt ~~ p~m ~ ~ak 14~ H~~ ~ad of M~ a T.D. ~15i ~da~ ~uE~ ~m ~ to ~I minute) 141~ ~uN~e~ M~ G~c G~ ~ .7~ ~d~ ~m [~abiliz~ 1~ _ ~uNa~ M~ WeMM, ~,,~k ~.P.G.) , 14,47! IS Ih~ a m~ t~ NO A~id~ m~lm~m BHP ~ finaLT~D. ~0 Volume VOlume ~ flu~ ~CHI~D F~TION INTE~ ~ST OF 14. 5 P~ E.M.W. ,,,,, --.~ . . . ~ ............. , ,, ,,, ,, , ~ ., , ,, ,, --~ ,.,, . , ,,~_~ ............ .. Psge ! Lea~ [ ~ · . 0 1 2 3 4 5 8 7 8 9 D14~ ~ ' -' // .~'~r~-~( , ~ ~ SZ--]T~-]~ TIME ~ ~S (~-x-) /~-- · ' I ~ ' [ ' , ~ } -- j , 0 4 ~ 12 t6 ~ ~ ~110 2 4 $~OK~ ~eakoffl .... ~.~ '~. , , ~ . , , . ~ tt~ ~ 12~ 1215 IfS: 1 -1~ 14¢0 ........... ~ ~ i ,., I 0 ........ . , , : , - , ~~~u~ I I -., . ,~, ~~~ ~ ~ .... [ . , .............. MEMORANDUM TO: David John~s~, Chairman' State of Alaska Alaska Oil and Gas Conservation Commission DATE: March 15, 1998 THRU: Blair Wondzeli, ~ J, ''~ = f~FILE NO: P. I. Supervisor - A6TJCNFE.DOC FROM: Lou Grimaldi, .~- SUBJECT: Petroleum Inspector BOP test Nabors 160 Forcenergy VVMR#5 West McArthur River Field PTD #"98-47 Saturday~ March 14~ 1998; I witnessed the initial BOP test on Nabors rig #160 drilling Forcenergy well WMR#5 in the West McArthur River Field. I arrived to find the rig not ready to test. I made a tour of the rig and found all necessary equipment to be in place and functional. The test, once started, went well, All BOPE were tested with two failures observed. The bottom pipe rams failed to hold pressure and required changing the inserts out. The manual choke valve also failed was greased and cycled. Both components passed their retest The Accumulator test time of 3 minutes and 16 seconds is slow for this type accumulator but normal for this dg. The Gas detectors were tested and were working properly. I made a check on the mud monitor system and found it to be working properly. SUMMARY: The initial BOPE test I witnessed on Nabors dg #160 revealed the following; Test time 4 hours, Two failures. Attachments: A6TJCNFE.XLS CC; Paul White Forcenergy NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: f3 3/8 Test: Initial X Workover: Neighbors Rig No. 160 PTD # Forcenergy Rep.: WMR #5 Rig Rep.: Set @ 2, f00 Location: Sec. . Weekly ~ Other ~ DATE: 3/14/95 98-47 Rig Ph.# 776-5580 Don Jones T, Bob Mize R. Meridian Test MISC. INSPECTIONS: Location Gen.: P Housekeeping: P PTD On Location P Standing Order Posted (Gen) Well Sign P Drl. Rig P Hazard Sec. P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure I 250/3,000 250/3,000 f 250/3,000 P/F P P P P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. 1 250/3,000 I 250/3,000 f 25073,000 f 250/3,000 f 250/3,000 2 250/3,000 1 250/3,000 N/A 250/3,000 P/F P P F P F P N/A MUD SYSTEM: V'sual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P' Meth Gas Detector P P H2S Gas Detector P P CHOKE MANIFOLD: No. Valves 12 No. Flanges 36 Manual Chokes 2 Hydraulic Chokes I Test Pressure 250/3,000 250/3,000 Funclfoned FuncSoned P/F P P P P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btrs: 3,000 [. P 1,450 P minutes 28 sec. minutes 16 sec. P Remote: P Five Boffies 2100 P~3. Number of Failures: 2 ,Test Time: 4.0 Hours. Number of valves tested 18 Repair or Replacement of Failed Equipment will be made within n/a days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. !. Supervisor at 279-1433 I REMARKS: Retested "OK" B. ottom pipe rams failed, replace inserts and retest 01~ Manual choke valve failed, replaced ~ate Distribution: odg-Well File c - Oper./Rig c - Database c - Tdp Rpt File c -Inspector FI-021L (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: W~nessed By: A6tjcnfe Louis R. Grimaidi TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION March 6, 1998 Paul White, Drilling Managcr Forccnergy Inc. 310 K Street Anchorage, AK 99501 Re: West McArthur River Wcll No. 5 Forccncrgy Inc. Permit No. 98-47 Sur. Loc.' 2066'FSL. 3336'FEL. Sec. 16. T08N. R14W. SM Btmholc Loc: 4423'FSL, 2243'FEL, Sec. 10, T08N, R14W, SM Dear Mr. X~fitc: 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Enclosed is thc approvcd application for permit to drill thc above referenced well. Thc permit to drill does not exempt you from obtaining additional pcrmits rcquircd by lax',' from other govcrnmcntal agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The new bottom-hole location will require a spacing exccption under 20 AAC 25.055. You are not authorizcd to open thc wcll to production until alter the Commission issues thc spacing exception following notice and opportunity for public hearing. Should an adjacent owner raise an objcction, the Commission mav require Forccncrgy to plug and abandon the well. Annular disposal of drilling waste will not be approvcd until sufficient data is submitted to ensure that 20 AAC 25.080 is mct. Annular disposal of drilling wastes xvill bc contingent on obtaining a well cemented surface casing confirmcd by a valid Formation Integrity Test (FIT) - cementing records. FIT data, and any CQLs must be submittcd to thc Commission prior to the start of disposal operations. Approval is given to waive logging surface and intermediate holes. Request for divcrtcr variance is approved. Blowout prevention cquipmcnt (BOPE) must be tested in accordancc with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of thc BOPE test performed before drilling below the surface casing shoe must be given so that a rcprcscntative of the Commission may witness the test. Notice may be given bv conic Commission petroleum field inspector on the North Slope pager at 659-3607. Robcrt N. Christcnson Commissioner BY ORDER OF THE COMMISSION dl f enclosures CC: l)epartment of I"ish & Game, I tabitat Section w/o encl. l)epartmcnt of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA O;:.rAND GAS CONSERVATION ,, OMMISSION PERMIT TO DRILL la. Type of work Drill: X Re-Entry: 2. Name of Operator Forcenergy Inc. 2O AAC 25.005 Redrill: I lb. Type of well Exploratory: Stratigraphic Test: Deepen: I Service: Developement Gas: Single Zone: 3. Address 5. Datum Elevation (DF or KB) 163' KB feet 6. Property Designation ADL-359111 7. Unit or property Name West McArthur River Unit Development Oil: x Multiple Zone: 10. Field and Pool West McArthur River Field West McArthur River Pool 310 K Street, Suite 700 Anchorage, Alaska 99501 4. Location of well at surface 2066' FSL, 3336' FEL, S16, T08N, R14W, SM At top of productive interval 3825' FSL, 2724' FEL, Sl0, T08N, R14W, SM At total depth 4423' FSL, 2243' FEL, Sl0, T08N, R14W, SM 13. Distance to nearest well 1007 feet 12. Distance to nearest property line 2243 feet 16. To be completed for deviated wells Kickoff de )th: 600' feet Maximum hole angle: 52 8. Well number West McArthur River Unit #5 9. Approximate spud date 10-Mar-98 14. Number of acres in property 4,175 11. Type Bond (see 20 AAC 25.025 Number Statewide Amount $500,000 15. Proposed depth (MD and TVD) 14,606' MD / 9,963' TVD feet 3650 psig 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 981 psig At total depth (I'VD) )rogram 18. Casing Setting Depth Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD (include stage data) Driven 20" 133# K-55 BTC 120' 0 0 n/a 17 1/2" 13 3/8" 68# L-80 BTC 12 1/4" 9 5/8" 47# L-80 BTC 8 1/2" 7 5/8" 29.04# HC-95 STL Hyd 511 2,208' 0 0 2,760 cu. Ft. 6,635' 0 0 847 cu. Ft. 171 cu. Ft. 5,880' 2,491' 6,435 12,115' 5 1/2" 4,880' 8,510' MD TVD 120' 120' 2,208' 2,150' 6,635' 5,000' 12,315' 8,663' 14,606' 9,963' 333 cu. Ft. 17# 6 3/4" L-80 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet true vertical feet Effective depth: measured feet true vertical feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size measured true vertical Cemented ORIGINAL Measured depth True vertical depth 20. Attachments: Filing fee: X Property Plat: X BOP Sketch: X Drillin,__,g fluid program: X Time vs. depth plot: X Refraction analysis: 21. I he4by c'~rtify that the foregoing is true and correct to the best of my knowledge: Signe'~/''~At,t,,~)% ~ ~k~)At'a~t,.,L'~v ,, Paul White Title: Drilling Manager Diverter Sketch: Drilling program: X Seabed report: 20 AAC 25.050 requirements: X Date: Commission Use Only by order of Commissioner the Commission Permit Number/.lz II APl number II Approval date 7 50-I -aow2 Conditions of approval Samples required: [ ] Yes ~ No Mud log required: [ ] Yes ~No Hydrogen sulfide measures [ ] Yes ~ No Directional su~ey required ~Yes [ ] No Required working pressure forBOPE [ ]2M; [ ]3M; [X]5M; [ ]10M; [ ]15M Other: Approved by ORIGINAL SIGNED BY ISee cover letter for other requirements Robert N Christenson Form 10-401 Rev. 12-1-85 ' Submit in triplicate Attachments lo 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. Waiver Requests Outline Procedure Well schematic Unit Boundary Plat Proposed Well Path Drilling Fluids Program Pressure Information Casing Design Cement Calculations Directional Information Well Head Schematic Nabors BOP schematic Nabors BOP equipment list Nabors Drilling Fluid System Description West McArthur River Unit Request for Diverter Waiver Forcenergy requests that the diverter requirements in 20 AAC 25.035 be waived for West McArthur River//5 because West McArthur River Unit No. 1, No. 2, No. 3,No. 4, No. D-1 and West Forelands Unit No. 2 were all drilled from the same general surface location without encountering any shallow gas. Previous waivers were granted for WMRU No. 2, No. 3, No. 4 and No. D-1. Mud weights planned for the surface interval are 8.5 ppg at spud building to 9.4 ppg at 2,150' TVD due to drilled solids. These mud densities are consistent with the 3 prior wells. Request to Eliminate Logging Runs at Surface and Intermediate Casing Points Forcenergy requests a waiver for the open hole wireline logging required by 20 AAC 25.071 at the surface casing point of 2,150' TVD and at the intermediate casing point of 5,000' TVD. West McArthur River Unit Wells No. 1, No. 2, No. D-1 and West Forelands Unit No. 2 have 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 No. 3 and West McArthur River Unit No.4. Request for Annular Injection in Intermediate Casing Annulus Forcenergy requests that the 9 5/8" annulus be used for annular disposal of Class II drilling fluids. The 13 3/8" casing shoe will be set significantly below any fresh water sands. West McArthur River Unit #5 OUTLINE PROCEDURE o 2. 3. 4. 5. 6. 7. 8. o 10. 11. 12. 13. 14. 15. 16 17 18 19 20 21 22. 23. 24. Move Rig, Rig Up, Drive 20" conductor to 120'. Rig flow line, Pick up BHA, Spud Well. Clean out conductor and drill to 600' Kick Off Point. Directionally drill 17 1/2" hole to 2,208' MD / 2,150' TVD. Run 13 3/8" casing to 2,226', cement to surface. Install wellhead, Nipple up and Test 13 5/8" 5m BOP stack and equipment Pick up 12 ~/~" BHA, Run in hole. Test casing to 2000 psi. Clean out casing and drill 20' of new hole. Perform Formation Integrity Test to 14.0 ppg EMW. Directionally drill 12 1fi,, hole to 6,635' MD / 5,000' TVD. Run and cement 9 5/8" casing. Nipple down BOPs. Install casing slips and packoff. Nipple up and Test 13 5/8" 5m BOP stack and equipment. Pick up 8 1/2" BHA, Run in hole. Test casing to 3000 psi. Clean out casing and change over to Oil Based Mud. Drill 20' of new hole. Perform Formation Integrity Test to 14.5 ppg EMW. test. Directionally drill 8 1/2" hole to 12,315'MD / 8,663' TVD. Run intermediate log suite. Condition hole, Run and cement 7 5/8" liner from 6,435' to 12,315'. Test 13 5/8" 5m BOP stack and equipment. Pick up 3 1/2" drill pipe / BHA and run in hole. Clean out liner and test lap to 3000 psi. Clean out shoe track, drill 20' of new formation and Perform Formation Integrity Test to 15.0 ppg EMW. Directionally drill 6 3~ ,, hole to TD at 14,606'MD / 9,963' TVD. Condition hole and run log suite as follows: Triple combo, FMI, RFTs (be prepared to run drill pipe conveyed logs) 25. Condition hole for liner. 26. Run and cement 5 1/2" liner from 12,115' to 14,606'. 27. Clean out liner and test lap to 3000 psi. 28. Run Cement Bond logs 29. Run 2 7/8" completion string with Tubing Conveyed Perforating guns. Stab completion into liner hanger polished bore, fire guns and place well to test. WMRU #5 Casing Design 20"133#,L-80 13 3/8" 68#, L-80 BTC,~ 9 5/8" 47#, L-80 BTC '~ 7-5/8" 29.04#, HC-95,~ 5-1/2" 17#, L-80 .~ @120' MD, 120'TVD @2208' MD, 2150'TVD @6635' MD, 5000'TVD @12,315' MD, 8663'"'1'VD 14,606' MD, 9,963' TVD West McArthur River Unit Unit Boundary Plat Proposed WMRU No. 5 TSN, R14W, Seward Meddian W. McArthur River Unit Forcenergy ADL 359111 4 3 WMRU #5 Proposed 17 20 29 /" #2A · · ~0 15 22 32 i 33 ADL 17602 Unocal 2 11 12 14 13 WMRU Forcenergy ADL 359112 27 23 Forcenergy ^ I 381012 26 35 24 25 36 1" = 1 mile _~~WEST FORELAND UNIT TVD TMD 980O 14651 T D T Heml o W~U-1A T RTHUR R I V~ R #2A ~ST McAi~THUR 1~ IVER aS West McArthur River Unit//5 DRILLING FLUID PROGRAM Interval Hole size = Casing Size = Mud type = 0' - 2,208' 171/2'' 13 3/8" Fresh Water Bentonite Drilling Fluid Parameters: Weight: 8.8 - 9.5 ppg PV: 5- 10 cps YP: 15-25 lb/100ft2 API Fluid Loss: n/c - 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 30 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 2,208' - 6,635' Hole size = 12 ¼" Casing Size - 9 5/8" Mud type = PHPA Polymer Drilline Fluid Parameters: Weight: 9.0- 9.5 ppg PV: 10- 12 cps YP: 12-25 lb/100fta 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 = 6,635'- 14,606' 81/2" 7 5/8" and 5 1/2" Flush Joint Invert Oil Base Drilling Fluid Parameters: Weight: 8.8 - 9.5 ppg PV: 15- 18 cps YP: 10-30 lb/100fta 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. Use the OBM from West McArthur River Unit//4 well, which was stored in the 1300 bbl storage tank and build additional volume as needed. 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. WEST MCARTHUR RIVER UNIT 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 (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 casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less 2/3 the caSing hydrostatic column of a 9.0 ppg mud and the remainder, a gas gradient to the surface. It is assumed that full evacuation of the casing is highly unlikely in a developed field with a normal gradient, low GOR (235 cu ft / bbl) and no known gas cap. 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- FPP-(0.115 x 1/3D) - (9.0 x .052 x 1/3D) where: FPP = Formation Pore Pressure at the next casing point which is tied back to surface or at TD (total depth) ASP Drilling Below 13 3/8" 1) ASP ((FG x .052) - 0.115) x D (( 11.5 ppg x .052)- 0.115) x 2150' 038 psi O1' 2) ASP =FPP-(0.115 x 1/3D) - (9.0 x .052 x 2/3D) =(.45 x 5000') - (0.115 x .33 x 5000') - (9.0 x .052 x .67 x 5000') - 492 psi ASP Drilline Below 9 5/8" 1) ASP = ((FG x .052) - 0.115) x D -- (( 15.0 ppg x .052)- 0.115) x 5000' = 3325 psi or 2) ASP = FPP-(0.115 x 1/3D) - (9.0 x .052 x 2/3D) =(.45 x 8663')- (0.115 x .33 x 8663') - (9.0 x .052 x .67 x 8663') = 853 psi ASP Drilling Below 7 5/8" 1) ASP ((FG x .052) - 0.115) x D (( 14.5 ppg x .052)-0.115) x 8663' 5536 psi or 2) ASP = FPP-(0.115 x 1/3D) - (9.0 x .052 x 2/3D) =(.45 x 9963') - (0.115 x .33 x 9963') - (9.0 x .052 x .67 x 9963') = 981 psi WEST MCARTHUR RIVER UNIT CASING DESIGN Setting Depth Size Specifications Top Bottom Hole Casing Weight Grade Coupling Length MD TVD MD 'rVD Driven 20" 133# K-55 BT&C 120' Surf. Surf. 120' 120' 17 1/2" 13 3/8" 684¢ L-80 BTC 2,202' Surf. Surf. 2,208' 2,150' 12 1/4" 9 5/8" 47# L-80 BTC 6,635' Surf. Surf. 6,635' 5,000' 8 ½" 7 5/8' 29.04# HC-95 STL 5,880' 6,435' 4,880' 12,315' 8,663' 6 %" 5 ~" 17# L-80 Hyd 511 2,491' 12,115' 8,510' 14,606' 9,963' Casing Joint Strength Body Strength Burst Collapse K lbs K lbs Psi Psi '20" 133# K-55 BT&C 2123 2125 3060 1500 13 3/8" 68# L-80 BTC 1585 1556 5020 2260 9 5/8" 47# L-80 BTC 1161 1086 7930 4750 7 5/8" 29.04# HC-95 STL 574 811 8176 5134 5.5" 17# L-80 Hyd 511 302 397 7738 6285 Desien Criteria Tension Straight Hook Load - Ignoring Deviation and Buoyancy Burst Full Column 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 .45 psi/ft, on the outside. 20" Conductor N/A 13 3/8" Casine Tension = 2208' x 68// Rated = 1556 K = 150.1 K Safety Factor = 10.4 Burst = (5000 x .45) - (.115 x 5000') Rated -- 5020 psi = 1675 psi Safety Factor - 3.0 Collapse -- (2150' x .45) - (.115 x 2150') Rated = 2260 psi - 720 psi Safety Factor = 3.1 9 5/8" Caslm, Tension = 6635' x 47// Rated = 1086 K = 311.8 K Safety Factor = 3.5 Burst = (9963 x .45) - (.115 x 9963') Rated ' 7930 psi = 3338 psi Safety Factor = 2.4 Collapse = (5000' x .45) - (.115 x 5000') Rated = 4750 psi = 1675 psi Safety Factor = 2.8 7 5/8" Drilling Liner Tension = 5880' x 29// Rated = 574 K = 170.5 K Safety Factor = 3.4 Burst = ((8663 x .4992)+3000)-(8663 x Rated = 8076 psi .43) Safety Factor - 2.2 - 3599 psi Collapse = (8663' x .45) - (.115 x 8663') Rated - 5134 psi = 2902 psi Safety Factor = 1.8 5 1/z" Production Liner Tension - 2491' x 17// Rated = 302 K = 42.3 K Safety Factor = 7.1 Burst = ((9963 x .4992) +3000)-(9963 x Rated = 7738 psi · 43) Safety Factor = 2.1 = 3689 psi Collapse = (9963' x .45) - (.115 x 9963') Rated = 6285 psi = 3338 psi Safety Factor -- 1.9 WEST MCARTHUR RIVER UNIT #5 CEMENTING PROGRAM SURFACE CASING WELL DATA DEPTH 2208' MD, 2150'TVD VOLUME REQUIRED 1534 cf HOLE SIZE 17 1/2" EXCESS 80% OH PIPE SIZE 13 3/8" OD, 68#/FT TOTAL VOLUME 2760 cf MUD WT 9 ppg TOP OF CEMENT Surface CEMENT Lead 12.5 ppg - 2260 cf slurry - Class G + 2%A-2 + 0.4%CD-31 + 0.5%A-7 + 1 ghs FP-6L Tail; 15.7 ppg- 500 cf slurry - Class G + 0.25% CD-31 + 1.5% A-7 + 1 ghs FP-6L INTERMEDIATE CASING WELL DATA DEPTH 6635'MD, 5000' TVD HOLE SIZE 12 ¼" PIPE SIZE 9 5/8"OD, 47#/FT MUD WT 9 ppg VOLUME REQUIRED EXCESS TOTAL VOLUME TOP OF CEMENT 659 cf 3O% 847 cf 4635' MD CEMENT Preflush 8.4 ppg - 50 bbls water containing 1% MCS-A Slurry.: 15.8 ppg - 847 cf slurry - Class G + .25% CD-31 + 0.25% A-7 + 1 ghs FP-6L West McArthur River Unit//5 CEMENTING PROGRAM DRILLING LINER WELL DATA DEPTH 12315 MD, 8663' TVD VOLUME REQUIRED 136 c£ HOLE SIZE 8 ½" EXCESS 30% PIPE SIZE 7 5/8"OD, 29.7# TOTAL VOLUME 171 cf MUD WT 9.5 ppg TOP OF CEMENT 10815' MD CEMENT Preflush: 8.4 ppg - 30 bbls Water comaining 1% MCS-A Slurry: 15.8 ppg - 171 cf slurry - Class G + 0.6% FL-20 + 0.2% CD-31 + 0.1% A-2 + 1 ghs FP-6L PRODUCTION LINER WELL DATA DEPTH 14606' MD, 9963' TVD VOLUME REQUIRED 270 cf HOLE SIZE 6 ~" EXCESS + 200' 7 5/8" 30% Open hole PIPE SIZE 5 1/2"OD, 17#/ft TOTAL VOLUME 333 cf MUD WT 10.0 ppg TOP OF CEMENT 12115' MD CEMENT Slurry: 15.8 ppg - 333 cf Class G + 0.85% FL-28 + 0.2% CD-31 + 0.15% A-2 + 1 ghs FP-6L Anadrill SchXu~herger Alaska District 1111 Ea6t S0tk Avemue A~chorage, AK 995T8 {901) 349-4511 Fax 544-2160 DZRECTION/kL W~LL PLAN for FORC~NERGY INC. Well ......... : WM~-5 Field ........ : West McA~hur River Unit Cc~,putation..: Minimum Curvatuze U~its ........ : PEET Surface Lat..: 60.78254915 N Surface Long.: 151.7467426~ Legal Descr£ution Surface ...... : 2066 FSL 3336 FEL S16 TOSN Rl%~ SM Tc3t He, flock..: ~825 FSL 272& FEL S~0 T~SN R14~ SM BHL .......... : 4423 FSL 22¢3 PEL S10 TOSN R14~ S~ LOCATIONS - A~SKA Zone: ~ X-Coord ¥-Coord 1~7849.~4 2482113.29 193915,00 24B8995.00 194%10.00 2489580.80 Prapared ..... : 05 Mar 1998 v~r% sect az.: ¢0.21 KB elevation.: 163.00 Magnetic Dc~n: %21.686 (H) Scale Factor.: Convergence..: ANADRfLL AKA-DPC APPROVED STATION E~ASUP~ED [NCLH IDENTIFICATION DEPT~ ANGLR 0.00 0.00 KOP/CURVE ~,00/100 600.00 0.00 700.00 ~.00 800.00 ~.00 1.50/100 900.00 3.00 CUlWE 2.00/100 mc:=:=mmm mmT=====mmm&mmm&m DIRI~CTION 1/ERTICAL-DSPTHS AZ I MlfI/{ TV~ SUB - SEA 0.OO 0.00 -L63.00 35.00 600.00 43~.00 35.00 699.9~ 5~6.99 35.00 799.96 6~6.96 35.00 899.86 736.B6 ~ ECT TOI~ COORDII~AT~$- DEPOT ~LL~ 0.00 0.00 N 0.00 0.00 N 0.00 0.87 0.71 N 0.S0 3.48 2.96 ~ 2.00 ~.B2 6.~3 N ~.50 1000.00 4.50 3~.00 999,65 636.65 14.33 11.79 ll00.OO 6.00 35.00 1099.22 936.22 23.45 19.2B 1200.00 7.50 35.00 1198,53 1035.53 35.~5 28.91 1250.00 B.2~ 35.00 124~.06 1055.06 i1.91 34.5~ 1300.00 9,25 35.00 1297.49 1134.i7 49.5~ 40.75 ALASKA Zone 4 TOOL K · FACH lO0 mmmmmmmm~ =:=:~mmmam :=== mmmm 1676&9.24 2482113.29 35R O.OO 187849.~4 248211~.29 35R O,O0 187949.~6 248~113.99 35R 1-00 157651.32 t4~2116.09 35R 1-00 8.26 E 1578~3.61 248212i.86 35~ 1,50 13.50 E L8~863.~5 24B2132.21 H~ t,S0 20,24 g L89B~0.2S 2462141.65 H~ 1.50 ~,17 ~ L~7674.32 2462147.~6 HS 1.5~ 28.54 E [87875.85 24821~3.~ HS 2.00 Z 3> 1~0.00 11.15 3~.00 [395.87 1~32.B7 6~,27 55,33 N 3B.?~ H 187869.&& 248Z167.5~ 8S 2.00 1500.00 13.25 35.00 1493.59 1330-59 88,40 72.71 N 50.91 E 187902.07 24~164.62 ~S 2.00 (AnadrilL (c)98 WMEtPO9 3.2C 6:20 PM 9) N STAT CON I DENTI Y [CAT 101~ CURVE 2.5o/noo 73-3/8" CSG PT END 2.50/100 CUR%rR CURVE 3.oo/loo TYONE K A END 3.00/100 MEASURED I14CLM DE ?TH ANGLE 1600.00 15.25 1650-00 16.25 1700.00 17.50 1800.00 20.00 1900.00 22.$0 2000.00 15.00 2100,00 27.50 2200.00 30.00 2207.83 30.20 2207.83 30.20 PROPO?F/D ~m. LL PROFrL~ DIRECTION VERTICAL-DEPTKS AZIMUTH TVD SUB-SEA 35.00 1590,61 1427.51 35.00 1638.63 1~75.63 55.00 1586.48 1523.(8 35.00 1674.)6 1711,36 SECTION DEPART 05 Mar 1998 Page COORDINATES - FROM :lmmummmmm 112.91 .91.B7 N 65.03 126.42 103.99 N ?2.81 140-88 LL$.B0 N 81.14 172.89 142.21 N 99.57 20~.98 171.89 R I20.36 35.00 1965-68 L$02,88 249.08 204.88 ~ 143.46 35.00 1055-56 L$92,56 293.13 24].11 N 168.B3 35,00 2L43-23 1980,23 34L.07 280.51 N 196.41 35.00 2150.00 ~987,00 344.93 283.72 N 198.67 36.00 2150-00 ~987.00 344.93 2R3.72 N 198.67 395.02 ~43.09 499.&4 560.03 624.67 2307.83 30.20 35.00 2400.00 3Z.91 35.97 2500.00 35.87 36.87 2600.00 38.83 37,66 2700.00 41.00 38,34 2236.4~ 2073 , 43 2314.99 2151,97 2397. &8 223& ,45 9.476 . 96 2313 ,96 2553.20 2390,20 2800.00 44.77 38.96 2625.99 2462,99 693.20 2900,00 47.74 39,$1 2695.12 2532,12 765.42 2922,26 48.41 39.62 2710.00 25~,O0 3000,00 50.72 ~0.01 2760.42 2597.42 ~41.15 3041,96 51.97 40,21 2766-63 ~623.6) $73.91 TYONEK B 3727,52 5~.99 40,21 3209,00 3046.00 1413,~1 TYOATEK C 4829.62 5~.97 (0.11 3~88.00 3725.00 2262.00 T3CONEK D ~46&.26 51.97 %0.21 4279.00 4116,00 2781.89 9-5/8" CS(3 PT 6634.54 51.97 40.2~ 5000.00 4837.00 3703.68 TYONEK E 6798,16 51.97 {0,1L 6333.00 6170,00 5407,91 ALASKA Zone & TOOL DL/ X Y FACE m=======---- 187916.72 2482204.40 KS 2.00 187924,80 2482215.31' KS 2.00 187933.43 2482226.9~ H~ 2.50 ~87952-56 2482252.~0 HS 2.50 187974.13 2482281.92 ~S ],50 187998.10 24S2314.29 HS 2.50 188024.~2 2482349.83 HE 2.50 188053.05 24~23&$.48 BS 2.5~ 186055.39 24~2391.63 ~S 2.50 18~055.~9 245239~.63 bL~ 2.50 324,92 N 364.19 N 409.62 N 457.89 N SOB.B6 N 227.$1 H 188085.32 2452432.05 LLR O.00 255,52 ~ 188114.36 24~2490.55 10K 3.00 289,07 ~ 18~149.11 44~2~15.08 9R 3.00 325.81 ~ 1881B7.12 24S2562.3] 9R 3.00 365,6S E 18822B.30 2482612.25 BR 3.00 562,39 618.34 631.11 676..55 701.61 %08.47 E 158272.53 24B2664.62 BR 3.00 ~54.16 E 158319.70 24B2719.34 7R 3.00 ~64.71 E L~8330.59 2482731.82 7R ].O0 502.60 E La8369.67 94~2776.24 7R 3.00 523.71 E 188391,44 ~&82B00.~3 ~S 3.00 lll$,O[ N 872.31 1776.98 N 1432.72 2168,75 N 1755.42 2062.73 N 2350.49 4164,27 N 3450.67 lg8950.~9 24B3203.7l ~R 0.00 189328.75 2483851.54 H8 0.00 189661,50 2484224.59 H8 0.00 190275,1~ 24~4912.50 H$ 0.0O 19~&09,S3 ~4~6184,31 HS 0.00 TYONEK F 10356.36 51.9'; ~0.21 7293.00 7130.00 6635.25 GO 12255.41 51.97 ~0.21 B463.00 8300.00 8131.08 9-5/~" CSO PT 12315.47 51.97 40.21 8500.00 8337.00 8178.39 5101.60 N 4243.00 6243.99 ~ 5208.65 6280.11 ~ 5239.LB ~92226.52 2487100.24 HH 0.00 /93222,23 2¢88216.$2 KS 0.00 193253.72 2&88251.82 H~ 0.00 "13 rq fAnadriiI (~)98 WMRSPO9 3.2C 6:20 L~4 P) ~ &'T~TION IDENTIFICATION CURVE 3.00/1~0 ~ ~.00/100 CURVE TOT j{EMDOCK WEST FORLAND 5-1/2' LI~ER PT TD PROPOSED WELL PROFILE DEPTK [NCLIq ANGLE =_ DIRECTION VERTICAL-DgPTRS ~ZIMUTH TVD SUB-SF3k 1345~.05 13500.00 13581.62 13581.52 13681.52 1~380.04 1%606.04 1&606.04 51.97 50.74 &8.42 48.42 SECTION DEPART 07 Mar 1998 COORDINATES - FRCHK WELt.H~AD 40.21 9203.32 9040.32 9077.5~ 6966.83 N 6819.66 39.71 9~30.15 9067.15 9111o12 6992.54 N 5541.~1 3S.?l 9283.00 9120.00 9173.17 7040.62 N S580.%{ 38.gl 9283.00 912~.00 9173.L7 70~0.62 N 5~80.4% 38.71 9203.0~ 9220.00 9173.17 7040.62 N $580~~% 38.71 9813.00 9650.00 9770.2, 38.91 9963.00 9800.00 9939-22 38.71 9963.00 9800.00 9939.22 7506.68 N 6253.98 7638.58 N 6359.7~ 7638.58 N 6359.70 P~ge 3 ALASKA Zone 4 TOOL DL/ X Y FACR l O (} 193872-27 2488922.86 L63L 0.00 193874.50 2A88947.99 L62L 3.00 19~915.00 2%88995.00 HS 3.00 1939L5.00 2488995.00 K~ 3.00 19391S.00 2485995.00 K~ 3.00 19%300.81 2489450.96 RS 0.00 19%4[0.00 245958~.00 0.00 19%410.00 2489580.00 0.00 ANAORILL AKA.DPC A'PPROVED (~nadrill [c}98 ~MRSP09 3.2C 6:20 PM P) ~ , FORCENERGY I NC... . . [ Aoa rj?] Schlumberger i i i i i :'XNADRILL AKA-DPC VERTICAL SECTION VIEW : '~: ' ~"'" TVD Scale.: ~ inch : ~800 feet JOep Scale.: ! inch : 1BO0 feet E' B] KOP/~UR~E 1.00/t00 600 ~00 0 0.0, ~rker Identification MD 8KB SECTN I~LI AJ KB 0 0 0 0.0~ C[ CURVE ~.50/~00 900 900 ~ 3.0 ....................................~ ~ ~x-~ho D} CURVE 2.00/100 1250 1248 42 .B.2~ ...... ..... ~_ ~ · E) CURVE 2.50/300 1650 1639 t25 ~6.~ ........... ~ ........ ~'~ F) ~3-3/8' CS6PT 2208 2150 345 30.2 - J} 9-5/6' CS6 PT 6635 5000 3704 K) 7-5/B' CS6 PT ]~15 8500 6~78 ~ L) CURVE 3.00/100 ]]~51 9~03 9078 5].9 M) END ~.00/~00 CURVE ]35~ 9~63 9173 ...... N) TGT HEXLOCK ]3582 9263 9t73 48. O} 5-~/2' LINER PT ~4606 9963 9939 48. P) TO ~460~ 9963 9939 ,, 'T~¢ ~ - ~ ............. '-"' ........ ~ i ~ - ~t~ ....................... ..... ~ , I ............................... mL ................... ~ ............ ~ ............ ~ ...... ~ ........ ._~ ........~ ................. ~,j_ ~ ..................... ~ ...... _ .............. ~ ............. . ............. . ............ O' 90~ i80~ 2708 3605 450~ 540~ §30~ 720~ B{O~ gO0~ 990~ ![OBOb It 70b i;~60b {3500 14400 35300 Sect ~on Oepae ture ii _ _ · _ i ii i i i mi ii ii i mm im FOR ,, M~PKeP Identification MD N/S E/W H) CURVE 3.oo/ioO 2308 325 N 228 I) END 3.00/~00 CURVE 3042 702 N 524 d) 9-5/8' CSG PT 6835 2863 N 2350 K) 7-5/8" CSG PT 12315 6280 N 5239 L) CURVE 3.00/100 13457 69G7 N 5820 M) END 3,00/100 CURVE 13582 7041N 5880 N) TGT HCMLDCK 13582 7041N' §BSO O) 5-1/2' LINER PT 14606 7639 N 6380 P) TD 14605 7639 N 6360 ii -' CENERGY I _. III WMR-5 (P09) PLAN VIEW CLOSURE ..... : 9939 feet at Azimuth 39.7f~ DECLINATION.: +21.686 (E) SCALE ....... : 1 inch = ~200 feet DRAWN ....... : 05 Mar t998 Il IIlll Anadri ]] Sch]umDerger [,.. 600 0 600 i200 i800 2400 3000 3600 4200 4BO0 5400 6000 6500 7200 <- WEST' EAST -> ~nadr~]l kig8 ~II,¢IsPOg 3.2C 6:20 PN P] i780o i imiiiiiii~i , i West McArthur River #~ Well Head Schematic 13 5/8' 3 M ZO' Casing 13 3~8' Casing 9 5/8' Casin9 2 7/8' Tubing . Nabors Rig #160 13-5/8" 5000 psi BOP Stack 13 5/8" 3N Head 3-1/8' Kill Line~ 1 = HCR Valve 2 = Gate Valve 13 3/8" Casing/ · 5000 psi Annular Preventer 5000 psi. Blind Rams Drilling Spool 5000 psi Pipe Rams 13 5/8" 3M 'x 5M: J. · ctor 4-1/16" Choke Line Nabors Rig #160 13-5/8" 5000 psi BOP Stack ,i i 5000 psi Annular Preventer ! 3-1/8' Kill Line~ I I = HCR Valve 2 = Gate Valve psi Pipe Rams 5000 '. 5000 psi Blind Rams Ddlling Spool 5000 psi Pipe Rams 4-1/16' Choke Line 13 BLOWOUT PREVENTION EQUIPMENT NABORS RIG NO. 160 13-5/8" BOP Equipment 3 ea 13-5/8" x 5000 psi wp ram type preventers (Hydril) 1 ea 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 1 ea 1 lot Thornhill Craver, automatic choke 3"- 10,000 psi with control choke panel Hydraulic pipe and fittings from manifold to BOP stack. DRILLING FLUID SYSTEM DESCRII~TION 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 1 ea 6 ea Derrick dual tandem shale shaker 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 · WELL PERMIT HECKLIST COMPANY gC'~.~_ct4~ WELLNAME t'7~//'V/ l~ FIELD & POOL C~, 2~ O / ('~ INIT CLASS l,~ '~d 1'- C~ ,' ( GEOL AREA ~"-- PROGRAM: exp I'q dev~ redrll [] serv [] wellbore seg [' ann. disposal para req~ ~ ,,1~(~ ' UNIT# /--% 0 ,/O ON/OFF SHORE © '1. ADMINISTRATION DATE A'I'J~R 9- (,:,-~ 1. Permit fee attached ...................... 2. Lease number appropriate ................... 3 Unique well name and number .................. 4. Well located in a defined pool ................. ~ N 5. Well located proper distance from drilling unit boundary .... Y ...~' 6. Well located proper distance from other wells .......... /.Y... N 7. Sufficient acreage available in drilling unit .......... ~ N 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 ........... REMARKS ENGINEERING APPR DATE GEOLOGY 14. Conductor string provided ................... ~ N 15. Surface casing protects all known USDWs ........... ~ N 16. CMT vol adequate to circulate on conductor & sud csg ..... N 17. CMT vol adequate to tie-in long string to surf csg ........ Y 18. CM"f wilt cover all known productive horizons .......... ~' N 19. Casing designs adequate for C, T, B & permafrost .... (..~N 20. Adequate tankage or reserve pit ................. Q~N 21. If a re-drill, has a 10-403 for abandonment been approved... Y i~ ~"~'~' 22. Adequate wellbore separation proposed ............. O N 23. If diverter required, does it meet regulations .......... Y N ~.~ 24. Drilling fluid program schematic & equip list adequate ..... (~ N 25. BOPEs, do they meet regulation ..... ,,,,.._.~.. ........ (~ N 26. BOPE press rating appropriate; test to '";:~:~'0t~> psig. ~ N 27. Choke manifold complies w/APl RP-53 (May 84) ........ N 28. Work will occur without operation shutdown ......... N 29. Is presence of H:,S gas probable ................. Y DA . 30. Permit can be issued w/o hydrogen sulfide measures. . -. '.- 31. Data presented on potential o.y.~e~p[essure'Zones ....... Y N 32. Seismic analysis_.o.f_shaltow'"~as zones ............. Y N ,, 33. Seabed.co~'iti~ survey (if off-shore) ............. Y N / 34. '~'~'namelphone for we.eklyprogress repqds ....... Y N lexploratory only] GEOLOGY: ENGINEERING: COMMISSION: RPC BEW DWJ .,~/~ JDH ~ i.~) ~ RNC~ co II(")W/ll~ - A \F("~[4'MSI,'t,,,L,I:;I r*,v Comments/Instructions: . . ,, r..o . ', - Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : FORCENERGY , INC. WELL NAi:fE : WEST MCARTH~'R RIVER UNIT #5 FIELD NAME : WEST MCART-HIIR RIVER UNIT BOROUGH : KENAI STATE : ALASKA API NUlq~ER : 50-133-20486-00 REFERENCE NO : 98217 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 08:44 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/05/ 2 ORIGIN : FLIC REEL NAME : 98217 CONTINUATION # : PREVIOUS REEL : COM~4ENT : FORCENERGY, WEST MCARTHURRIVER, W. MCARTHUR RIVER UNIT #5,50-133-2 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/05/ 2 ORIGIN : FLIC TAPE NAME : 98217 CONTINUATION # : 1 PREVIOUS TAPE : COF~4ENT : FORCENERGY, WEST MCARTHUR RIVER, W. MCARTHUR RIVER UNIT #5,50-133-2 **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01AiO DATE : 98/05/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : ** ** SCHLUMBERGER WELL SERVICES ** ** ******************************************************************************* COMPANY NAME: Forcenergy, Inc. WELL: West McArthur River Unit #5 FIELD: West McArthur River Unit BOROUGH: Kenai STATE: Alaska API NUMBER: 50-133-20486-00 LOCATION: 2066' FSL & 3336' FEL SECTION: 16 TOWNSHIP: 8N RANGE: 14W PERMANENT DATUM: MSL ELEVATION: O' LOG MEASURED FROM RKB 163' ABOVE PERMANENT DATUM LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 08:44 PAGE ELEVATIONS KB: 163' GL: 133.7' DATE LOGGED: 26-April-98 RUN NUMBER: One TD DRILLER: 14555 ' CASING 1: 7.625" @ DRILLER DEPTH OF 12858' AND LOGGER DEPTH OF 12854' BIT SIZE 1: 6.75" @ 14555' TYPE FLUID IN HOLE: Oil Based Nud DENSITY: 9 VISCOSITY: 128 TIME CIRCULATION ENDED: 0530 26-APR-98 TIME LOGGER ON BOTTOM: 0600 27-APR-98 MAXIMUM TEMP RECORDED: 174 DEGF LOGGING DISTRICT: Kenai, AK LOGGING ENGINEER: B.A. Woodard WITNESS: Art Saltmarsh FIELD REMARKS: Primary Depth Log. One inch standoffs used on the DIT and BHC Sonic. Maximun deviation is 55 degrees. No bowspring used on CNTdue to hole size. DATE JOB STARTED: 2-MAY-98 JOB REFERENCE NO: 98217 LDP/ANA: R. KRUWELL FILE -EDIT. O01 FORCENERGY, INC. WEST MCARTHUR RIVER UNIT WEST MCARTHUR RIVER UNIT 50-133-20486-00 "SONIC, LDT, CNL LOG DATA" DATA SAMPLED EVERY-.5000 FEET DATA INCLUDED - TOOL EXTENSION TOOL LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 08: 4~ PAGE: * TYPE USED NAME . * SDT .SDT ARRAY SONIC * LDT . SDT LITHO DENSITY * CNT-A/D/H . SDT COMPENSATED NEUTRON ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 152 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 6 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1038731 O0 000 O0 0 1 1 1 4 68 0000000000 DT SDT US/F 1038731 O0 000 O0 0 1 1 1 4 68 0000000000 TT1 SDT US 1038731 O0 000 O0 0 1 1 1 4 68 0000000000 TT2 SDT US 1038731 O0 000 O0 0 1 1 1 4 68 0000000000 TT3 SDT US 1038731 O0 000 O0 0 1 1 1 4 68 0000000000 TT4 SDT US 1038731 O0 000 O0 0 1 1 1 4 68 0000000000 GR SDT GAPI 1038731 O0 000 O0 0 1 1 1 4 68 0000000000 CALI SDT IN 1038731 O0 000 O0 0 1 1 1 4 68 0000000000 TENS SDT LB 1038731 O0 000 O0 0 1 1 1 4 68 0000000000 MTEMSDT DEGF 1038731 O0 000 O0 0 1 1 1 4 68 0000000000 MRES SDT OhlVk41038731 O0 000 O0 0 1 1 1 4 68 0000000000 HTEN SDT LB 1038731 O0 000 O0 0 1 1 1 4 68 0000000000 DPHI SDT PU 1038731 O0 000 O0 0 1 1 1 4 68 0000000000 RHOB SDT G/C3 1038731 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center .. 15-MAY-1998 08:4~-'~" PAGE: 4 NAME SERV UNIT SERVICE API API API API FILE ~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE C~SS MOD NUMB SAMP ELEM CODE (HEX) DRHO SDT G/C3 1038731 O0 000 O0 0 1 1 1 4 PEF SDT 1038731 O0 000 O0 0 1 1 1 4 QLS SDT 1038731 O0 000 O0 0 1 1 1 4 QSS SDT 1038731 O0 000 O0 0 1 1 1 4 LS SDT CPS 1038731 O0 000 O0 0 1 1 1 4 LU SDT CPS 1038731 O0 000 O0 0 1 1 1 4 LL SDT CPS 1038731 O0 000 O0 0 1 1 1 4 LITH SDT CPS 1038731 O0 000 O0 0 1 1 1 4 SSi SDT CPS 1038731 O0 000 O0 0 1 1 1 4 SS2 SDT CPS 1038731 O0 000 O0 0 1 1 1 4 LSHVSDT V 1038731 O0 000 O0 0 1 1 1 4 SSHV SDT V 1038731 O0 000 O0 0 1 1 1 4 S1RH SDT G/C3 1038731 O0 000 O0 0 1 1 1 4 LSRH SDT G/C3 1038731 O0 000 O0 0 1 1 1 4 LURH SDT G/C3 1038731 O0 000 O0 0 1 1 1 4 NPHI SDT PU 1038731 O0 000 O0 0 1 1 1 4 RTNR SDT 1038731 O0 000 O0 0 1 1 1 4 TNPH SDT PU 1038731 O0 000 O0 0 1 1 1 4 TNRA SDT 1038731 O0 000 O0 0 1 1 1 4 NPOR SDT PU 1038731 O0 000 O0 0 1 1 1 4 RCNT SDT CPS 1038731 O0 000 O0 0 1 1 1 4 RCFT SDT CPS 1038731 O0 000 O0 0 1 1 1 4 CNTC SDT CPS 1038731 O0 000 O0 0 1 1 1 4 CFTC SDT CPS 1038731 O0 000 O0 0 1 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 * * DA TA * * DEPT. TT3 . SDT TENS. SDT DPHI. SDT QLS. SDT LL. SDT LSHV. SDT LURH. SDT TNRA. SDT CNTC. SDT 14251 500 458 3540 27 -0 301 1587 2 1 4548 DT. SDT 63. 000 TT1. SDT 000 TT4 . SDT 325. 200 GR. SDT 000 MTEM. SDT 173. 643 I4RES. SDT 573 RHOB.SDT 2.195 DRHO.SDT 023 QSS. SDT O . O10 LS. SDT 664 LITH. SDT 111 . 462 SSi . SDT 115 SSHV. SDT 1658. 717 S1RH. SDT 088 NPHI. SDT 15. 839 RTNR. SDT 419 NPOR. SDT 11 . 951 RCNT. SDT 678 CFTC. SDT 3259. 825 DEPT. TT3 . SDT TENS. SDT DPHI. SDT QLS. SDT LL. SDT LSHV. SDT LURH. SDT TNRA. SDT CNTC. SDT 3916 500 DT. SDT -999 250 TT4. SDT 3255 000 MTEM. SDT 70 825 RHOB. SDT -0 180 QSS.SDT 826 347 LITH. SDT 1551 414 SSHV. SDT 1. 465 NPHI.SDT 3. 868 NPOR. SDT 1408. 683 CFTC. SDT 67. 900 TT1. SDT -999. 250 GR. SDT 114. 112 NIEES. SDT 1. 481 DRHO. SDT O . 073 LS. SDT 199. 742 SSi . SDT 1630. 112 S1RH. SDT 56. 866 RTNR. SDT 43 . 720 RCNT. SDT 373. 572 437. 200 TT2. SDT 318. 000 35. 850 CALI. SDT 2. 491 -1 . 200 HTEN. SDT 4399. 387 O. 131 PEF. SDT 4. 665 565. 491 LU. SDT 527. 656 284. 398 SS2. SDT 396. 044 1 . 807 LSRH. SDT 2. 068 1. 462 TNPH. SDT 11. 951 4685.169 RCFT. SDT 3175.417 -999.250 TT2.SDT 22 969 CALI.SDT -3 0 1702 284 1 4 1328 -999. 250 2. 468 100 HTEN. SDT 5092. 246 054 PEF. SDT 12. 254 183 LU. SDT 1751 . 674 686 SS2. SDT 413. 503 3 O1 LSRH. SDT 1 . 429 250 TNPH. SDT 46. 799 438 RCFT. SDT 390. 242 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 08:44'~ PAGE: ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01AIO DATE : 98/05/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01AiO DATE · 98/05/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE -EDIT. O02 FORCENERGY, INC. WEST MCARTHUR RIVER UNIT WEST MCARTHUR RIVER UNIT #5 50-133-20486-00 "DITE LOG DATA" DATA SAMPLED EVERY-.5000 FEET DATA INCLUDED - TOOL EXTENSION TOOL TYPE USED NAME DIT-E .DIT PHASOR DUAL INDUCTION SFL 15-MAY-1998 08:44 LIS Tape Verification Listing Schlumberger Alaska Computing Center PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 * * SET TYPE - CHAN * * NAME SERV UNIT SERVICE API API API API FILE NUFiB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~rtrMB SA=~P ELEM CODE (HEX) DEPT FT 1038731 O0 000 O0 0 2 1 1 4 68 0000000000 CIDP DIT ~ff~HO 1038731 O0 000 O0 0 2 1 1 4 68 0000000000 IDPH DIT OH~4M1038731 O0 000 O0 0 2 1 1 4 68 0000000000 CIMP DIT I~ffHO 1038731 O0 000 O0 0 2 1 1 4 68 0000000000 IMPH DIT OH~4M1038731 O0 000 O0 0 2 1 1 4 68 0000000000 CILD DIT Fk/iHO 1038731 O0 000 O0 0 2 1 1 4 68 0000000000 ILD DIT OH~ff41038731 O0 000 O0 0 2 1 1 4 68 0000000000 CILMDIT I~4HO 1038731 O0 000 O0 0 2 1 1 4 68 0000000000 ILM DIT Otff4M1038731 O0 000 O0 0 2 1 1 4 68 0000000000 IDQF DIT 1038731 O0 000 O0 0 2 1 1 4 68 0000000000 IMQF DIT 1038731 O0 000 O0 0 2 1 1 4 68 0000000000 SFLU DIT OH~4M1038731 O0 000 O0 0 2 1 1 4 68 0000000000 SP DIT MV 1038731 O0 000 O0 0 2 1 1 4 68 0000000000 GR DIT GAPI 1038731 O0 000 O0 0 2 1 1 4 68 0000000000 TENS DIT LB 1038731 O0 000 O0 0 2 1 1 4 68 0000000000 MTEMDIT DEGF 1038731 O0 000 O0 0 2 1 1 4 68 0000000000 MRES DIT OH~ff41038731 O0 000 O0 0 2 1 1 4 68 0000000000 HTEN DIT LB 1038731 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 08:4~ ..... PAGE: DEPT. 14250.000 CIDP.DIT IMPH.DIT 14.125 CILD.DIT ILM. DIT 13.802 IDQF.DIT SP.DIT -787.500 GR.DIT MRES.DIT -2.100 HTEN.DIT DEPT. 12780.500 CIDP.DIT IMPH.DIT 1950.000 CILD.DIT ILM. DIT 45.534 IDQF.DIT SP.DIT -1047.938 GR.DIT MRES.DIT -1.100 HTEN.DIT 67.873 IDPH. DIT 69.997 ILD.DIT 0.000 IMQF.DIT 25.233 TENS.DIT 474.050 38.189 IDPH. DIT 33.235 ILD.DIT 0.000 IMQF. DIT 42.198 TENS.DIT 747.823 14.733 CIMP.DIT 14.286 CILM. DIT 0.000 SFLU.DIT 3715.000 MTEM.DIT 26.186 CIMP.DIT 30.088 CILM. DIT 0.000 SFLU. DIT 6215.000 MTE~I. DIT 70.797 72.451 9700.000 175.392 -10.141 21. 962 9700. 000 168. 960 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01AIO DATE : 98/05/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAI4E : EDIT DATE · 98/05/ 2 ORIGIN · FLIC TAPE NAME : 98217 CONTINUATION # : 1 PREVIOUS TAPE : CO~R4ENT · FORCENERGY, WEST MCARTHUR RIVER, W. MCARTHUR RIVER UNIT #5,50-133-2 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/05/ 2 ORIGIN : FLIC REEL NAME · 98217 CONTINUATION # : PREVIOUS REEL : CO~R4ENT : FORCENERGY, WEST MCARTHUR RIVER, W. MCARTHUR RIVER UNIT #5,50-133-2 ,IS Tare Verificatior, !..i. st:fnq ~chlUm.~ercjer g Ka Corr, put.lnfj Center 19-;90¥-199.3 !3:49 PAGE: 26 ~8 07 636 21. 0 6 1. 1 4, 6~ 8000000000 ~ 07 636 21 0 6 ~. ] 4 68 8000000000 F't!..I~ 07 636 21 0 6 !. I ? 49 8200000000 F' 07 636 21 0 6 1 ~ 4, 68 8000020000 07 636 21 0 6 1, ~. 2 79 ~000020000 b~':~F 07 0~5 2!. 0 6 ~. 1 4 6~ 8000000000 F' ~)7 !50 O! 0 6 ~ ~ 2 49 8O00000000 I~x, <)7 2!~0 Ol {) 6 ~ 1. 2 49 8000020000 I~ o7 280 (~1 t~ 6 1 ~ 2 a9 84013000000 F3 (~7 282 01. 0 6 ~. ~ 2 49 8400000000 ~3 O7 ~2 O! 0 6 ! ~ 2 49 8400000000 ~ 07 ]5~ O0 0 6 ~. 1. ~ 49 9000020600 v ~)7 35a 0{} 0 6 I I 2 49 9000020000 (?PS :37 354 02 0 6 ~ 1 2 49 8000020000 CPS o7 354 02 0 6 ! 1 2 49 8000020000 CP~ 07 354 02 0 t, ! 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