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208-196
ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Date: May 27, 2025 FFROM:Anu Ambatipudi TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC 700 G Street 333 W.7th Ave., Suite 100 Anchorage AK 99501 Anchorage, Alaska DATA TRANSMITTAL Kuparuk River Unit/Field Well API #PTD #Comments 1H-112 50029237870100 2240320 3B-16A 50029212890100 2231250 2B-03B 50029211510200 2230800 2M-39 50103207950000 2181710 3S-612 50103207770000 2181110 3S-611 50103207740000 2181030 1H-108B 50029236080200 2180820 1H-110 50029236010000 2180310 1H-116 50029235940000 2180120 2S-06 50103207470000 2160850 2M-37 50103207450000 2160820 1D-39 50029229970000 2002160 1D-40A 50029229690100 2001900 2N-302 50103203800000 2011150 1R-03A 50029214060100 2000210 3H-37 50103208220000 2191940 2S-09A 50103207490100 2161280 T40450 T40451 T40452 T40453 T40454 T40455 T40456 T40457 T40458 T40459 T40460 T40461 T40462 T40463 T40464 T40465 T40466 By Gavin Gluyas at 1:15 pm, May 28, 2025 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Colville River Unit/Field Well API # PTD # Comments CD5-31 50103208280000 2210020 CD5-96 50103208110000 2191620 CD4-499 50103208100000 2191610 CD5-26 50103208060000 2191070 CD5-98 50103208030000 2190590 CD5-24 50103207990000 2190060 CD5-23 50103207610000 2171550 CD5-19 50103207600000 2171210 CD5-22 50103207590000 2170890 CD5-316 50103207560000 2170400 CD3-111A 50103205260100 2170040 CD3-198 50103206370000 2110240 CD4-24 50103206020000 2090970 CD4-26 50103206000000 2090490 CD2-15 50103203860000 2011590 CD2-12 50103204550000 2030730 CD4-214 50103205370000 2061450 CD4-17 50103205340000 2061180 CD2-73 50103205900000 2081960 T40467 T40468 T40469 T40470 T40471 T40472 T40473 T40474 T40475 T40476 T40477 T40478 T40479 T40480 T40481 T40482 T40483 T40484 T40487 CD2-73 50103205900000 2081960 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Greater Mooses Tooth Unit/Field Well API # PTD # Comments MT7-99 50103208450000 2221020 T40485 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 21, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Matt Herrera P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD2-73 COLVILLE RIV UNIT CD2-73 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/21/2022 CD2-73 50-103-20590-00-00 208-196-0 W SPT 6941 2081960 1735 1589 1588 1589 1589 737 749 749 749 4YRTST P Matt Herrera 6/28/2022 MIT-IA Performed to 2500 PSI Per Operations 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:COLVILLE RIV UNIT CD2-73 Inspection Date: Tubing OA Packer Depth 520 2500 2450 2450IA 45 Min 60 Min Rel Insp Num: Insp Num:mitMFH220629151411 BBL Pumped:4.3 BBL Returned:4.3 Thursday, July 21, 2022 Page 1 of 1 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 10, 2020 Commissioner Jesse Chmielowski Alaska Oil & Gas Commission 333 West 7`h Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jesse Chmielowski: RECEIVED Mpl,'Y 13 2020 AOCCC Enclosed are the spreadsheets with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement/sand if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement/sand was installed April 215f thru April 24`h, 2020. The corrosion inhibitor/sealant was pumped on April 22°d thru April 25`h, 2020. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sincerel !, � Roger Winter ConocoPhillips Well Integrity Field Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) Alpine Field Date 5/10/2020 CD2, 3, 4 & MT6 Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement/Sand top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal CD2 -02 *501032051300 2051090 30" 14 gals 9" 4/24/2020 1.5 4/25/2020 CD2 -73 *501032059000 2081960 11" 1 gal 6" 4/24/2020 0.5 4/2512020 CD2 -468 *501032058700 2081800 11" 1 gal 7" 4/24/2020 0.8 4/25/2020 CD3 -111A *501032052601 2170040 14" 4 gals V. 4/21/2020 1.3 4/22/2020 CD3 -198 *501032063700 2110240 10" 10" 3 4/22!2020 CD4 -215 *501032053900 2061570 40" 28 gals 9" 4/23/2020 1.4 4/23/2020 CD4 -291 *501032067200 2131100 2r 80 gals 6" 4/23/2020 0.5 4/23/2020 CD4 -321 *501032053600 2061420 18.5' 4 gals 6" 4/23/2020 0.5 4/23/2020 MT6-02 *501032079200 2181600 30" 14 gals 8" 4/23/2020 1 4/24/2020 MT6-03 *501032077000 2180160 49" 32 gals 10" 4/23/2020 1.7 4/24/2020 MT6-04 *501032077500 2181080 24" 17 gals 8" 4/23/2020 1 4/24/2020 MT6-05 *501032077100 2180450 30" 10 gals 7" 4/23/2020 1.3 4/24/2020 MT6-06 *501032077300 2180930 25' 7 gals 8" 4/23/2020 1 4/24/2020 MT6-08 *501032077200 2180480 12" 2.5 gals 7" 4/23/2020 1 4/24/2020 MT6-09 *501032077900 2181340 34" 15 gals 9" 4/23/2020 1.5 4/24/2020 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday,June 12,2018 Jim Regg }� P.I.Supervisor I\ f/13 1 l SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. CD2-73 FROM: Brian Bixby COLVILLE RIV UNIT CD2-73 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv � -- NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD2-73 API Well Number 50-103-20590-00-00 Inspector Name: Brian Bixby Permit Number: 208-196-0 Inspection Date: 6/7/2018 ,i Insp Num: mitBDB180611055405 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD2-73 Type Ind G 'TVD 6941 Tubing 3870 ' 3875 3870 ' 3870 - PTD 2081960 Type Test SPT Test psi 1735 ' IA 1090 2190 - 2170 ' 2170 - BBL Pumped: rr 2A • BBL Returned: 2.3 OA 186 - 188 • 188 - 188 ' Interval 4YRTST P/F P Notes: SCANNED JUN 2 LUi6 I, Tuesday,June 12,2018 Page 1 of 1 RECEIVED • • STATE OF ALASKA • • ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 2 7 2018 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ AGG '—Gwn ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑✓ Re-enter Susp Well ❑ SC Repair❑., 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 208-196 3.Address: P. O. Box 100360,Anchorage, Alaska Stratigraphic❑ Service ❑✓ 6.API Number: 99510 50-103-20590-00 7.Property Designation(Lease Number): 8.Well Name and Number: CRU CD2-73 ADL0380075/ADL0387207/ADL0387212/F EE/ASRC 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 21,810 feet Plugs measured None feet true vertical 7,328 feet Junk measured None feet Effective Depth measured 21,810 feet Packer measured 16,449 feet true vertical 7,328 feet true vertical 6,942 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 feet 16 " 114' MD 114'TVD NA NA SURFACE 3,621 feet 10 3/4 " 3,657' MD 2,384'ND NA NA INT.-UPPER 3,835 feet 7 5/8" 3,870' MD 2,459'TVD NA NA INT-LOWER 13,303 feet 7 5/8" 17,173' MD 7,196'TVD NA NA Tubing(size,grade,measured and true vertical depth) 4.5" L-80 16,519' MD 6,967'TVD SSSV:DB NIPPLE 2,326'MD 1,910'TVD Packers and SSSV(type,measured and true vertical depth) BAKER PREMIER PACKER 16,449' MD 6,942'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: Subsequent to operation: 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑., Exploratory ❑ Development ❑ Service ❑.i Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG E GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317--200 Roger Mouser Contact Name: Roger Mouser/Roger Winter Authorized Name: 9 Authorized Title: Well Integrity Field Supervisor Contact Email: N1927@conocophillips.com 2/25/2018 Contact Phone: 907-659-7506 Authorized Signature: � 171A474- / Dat A A/4f RBENVIS Vv FEE ' K18 Form 10-404 Revised 4/2017 Submit Original Only • • ~"..' • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 February 25, 2018 Commissioner Hollis French Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner French: Enclosed please find the 10-404 for surface casing repair on well CD2-73, PTD 208-196, Sundry 317-200. Please contact Roger Winter or Roger Mouser at 659-7506 if you have any questions. Sincerely, -te•b01747.1.677 Roger Mouser Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Enclosures: Summary of work 10-404 Pictures of damage and repair • CD2-73 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 02/01/18 Cut and remove conductor to expose surface casing. 02/02/18 Clean surface casing and found hole 69" below bottom of flutes. 02/03/18 AOGCC inspector Brian Bixby witnessed damage to surface casing. 02/17/18 Complete welding sleeve over exposed surface casing. 02/18/18 AOGCC inspector Bob Noble witnessed repair of surface casing. 02/18/18 SCIT complete. No visual external leaks observed. 02/19/18 Normal up conductor and begin back fill operations. le $1 ,. w 1 `i ta, i. ti , , P'w € ° Ift..„.<, , 10,„.‘ 1 g a r:. ,, ,. *.':, ,,,,,ii All' 1 k t. 4. I H r t a .„ y € b &o (`,' 4 �� —, 1 LI 0 , € 's€ " € y. Hwy p, • 8 A �y .T� W G S A 'g' 5 �" i e � X13' �' ...1„ , : . , ,_ , ....,....... ....„. 4 +^AMa�� 9 ., \:,,,,,,,.1 ,.... .war.«,. .>E..., ., Q r _ ... ,.. ' - - . , . . I, .. , . . • ... , . , ,.... T ... ,it :5._ ,t.: 1,„ ,..1. � r 004• ,% 4'j,. J fi,;-../.f A �1.M' likuAlt IL, M 4. it INA„. x � ' ,, i' w it t -'47 .. All rights reserved. This ` � .rovided to the AOGCC with �` copy for'its own use. Copying r purpose or by any other party is�� without the express'consent of " � i ask Inc t oi, �., 11 Alaska, • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg `, l 31•I 1S DATE: 2/19/2018 P. I. Supervisor FROM: Bob Noble SUBJECT: Surface Casing Repair Petroleum Inspector CRU CD2-73 CPAI PTD 2081960; Sundry 317-200 2/18/2018: I met with ConocoPhillips representative Roger Winter in the Alpine camp and discussed what CPAI was doing and had done with the casing repair on CRU CD2- 73. He told me that they had just completed patching the failed surface casing. He also v. said that they had just received a passing QC inspection on the welds. We then traveled to location to inspect the patch. The patch looked good to me and I instructed Rodger to go ahead and install the conductor. Attachments: Photos (4) o soot 2018-0218_Surface_Casing_Repair_CRU_CD2-73_bn.docx Page 1 of 4 • • 1.6, . U 1.0I �+ N Q �� U I a :r U R ¢ O S -; F R t Z pCid er, U t (6 mt , 0 ,CO CA O 4) �' oo N ...' oo H CI N —' t N l''.. 0 .:i.r. . i ,''' '- ' — 7 4 ,._ ,. . ...,. . , ::. tt!rt -, - ., it th.....i a) ^U +co Irr ii ' cc )M1 L co�ci a U i' Q U o00 '_ -- o .1p",5.;'.,, C.) CO o (0 _. `t ° N ., r = t1- . w - co r1 N 0 • • ��t, a o .a2 a ... ; , .ioc NRte � •I ¢ _ Yad 15 1. o LNa � O y tl o � o c b' .11,-.... �'t. 0 GUc n w., e .� t%L , a'- Q1 1�tpp i- # �/ 6 k �� U �I� � yr •c W p ¢' p CD rn bq c� to T a I A • U p CI1 U j I �+ ��a 0° cv 00 • 0 CNI o e. A Or 4 -, , ..'" 'd , , „, .. t. ' _[. , .. , � . i; il rte . . A' • ' ,. • • i " ' - .- -..,,_ s �� 1 S • en I co 0. s so rsi n p t"..1.N�j L U,u o c v • 120 t •L• 4A vii 7� ++ O E C % ' a +., . co r=4y 0 O � • - U L . U � .` co .7r (_'� G i. 3 '. o0 U 4.03s c o0 Ki 00 '....•'',2. S L __. .. . r-1 '9r � NO w .,. : '--,�. • t • k • A x • • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Reggtill 8 DATE: February 7, 2018 P. I. Supervisor FROM: Brian Bixby SUBJECT: Surface Casing Repair Petroleum Inspector CRU CD2-73 ConocoPhillips Alaska Inc. PTD 2081960; Sundry 317-200 02/03/2018: I arrived at location and met up with Roger Winter(Well Integrity; ASRC Contractor). I looked over the casing and took pictures (after excavation and cleaning of pipe; prior to repairs). The lowest picture is at 21 feet from surface. Roger mentioned that they are hoping to be able to have this well back on full injection and allowed to inject MI gas. From what I looked at this casing the integrity does not appear to be improving with depth. Based on what I observed, I question returning the well to any injection. Ft,A.L4v, e4241 Attachments: Attachments: Photos (7) AO C `L, pitfer-5 t n,,.t .uce J( pe / scANNEp „ ti i! 2,11<< 2018-0203_Surface_Csg_Repair_CRU_CD2-73_bb.docx Page 1 of—5 • • Surface Casing Damage — CRU CD2-73 (PTD 2081960) Photos by AOGCC Inspector B. Bixby 2/3/2018 m_= to i/ i II. Z. fl"'"v-). -4 - _ "r.dcf%- , "f1 s„ ``c'sj vrr ,.•' pT r sof i ..s Y` `;. ' iff'No • r�. Severe corrosion at-6ftfrom N> surface T NJ j < _. F' { v i x Vis= Mv }- " . 1 2018-0203_Surface_Csg_Repair_CRU_CD2-73 bb.docx Page 2 of 5 • • 1 I\ ,t . \ \ 'x�a ro ,� .1 i.‘ A Co A ‘4\14,:r44 m -A t0 . , . ,.., J. ...,... ,•,..,,, .-,$' .... .... • , ,, , , ,„ . Corrosion at-,21 ft from surface w. 0000,, 7 .4.: ..... .:.,,, „ ,,,,...7.' ' �� � ' t x 1p .» 2018-0203 Surface_Csg_Repair_CRU CD2-73_bb.docx Page 3 of 5 0 0 anti -,ig.:'-' • ,....., , t Surface casing IF repair planned at-21 ft \ ., , IVIR r I , , v. ' „ •� '': .� Surface casing ' � corrosion near d surface , 1 ` r ',11 .' ' ,.:1;,,,'..,:` .., / ,, ;;. , 2018-0203 Surface Csg Repair CRU_CD2-73 bb.docx Page 4 of 5 0 0 y$ y ( - .k firms: , .,, :4011,,......,,,„.. .. Surface casing . , ' : 4ii � <�;'���'�� repair planned . r 11. ' '''''''''''''';'1. . , -'-,.,„ :. 1 ,. , ) 2018-0203_Surface_C sg_Rep air_CRU_CD2-73_bb.docx Page 5 of 5 • • 8..OF T4i g-0\1//7,'sem THE STATE Alaska Oil and Gas F -s �, of T ® c 1A Conservation Commission It itC ._ .— 333 West Seventh Avenue '141;-117011* GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 °'ALAS*� Fax: 907.276.7542 www.aogcc.alaska.gov Roger Winter SCANNED MAY 3 f 2;ri i j WI Field Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Colville River Field,Alpine Oil Pool, CRU CD2-73 Permit to Drill Number: 208-196 Sundry Number: 317-200 Dear Mr. Winter: 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, °-16: P--- -et.od.----- Cathy P. oerster 2-lit-lay �� - Chair DATED this day of May,2017. RBDMS t,(---MAY 2 4 2017 0 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 1 5,201? APPLICATION FOR SUNDRY APPROVALS 'Ts sl2s l47 20 AAC 25.280 AOG 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well 0' Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing ❑ SC Repair 0• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory ❑ Development ❑ 208-196 3.Address: 6.API Number:�0 _ Stratigraphic ❑ Service E. _ oda_op P.O.Box 100360,Anchcorage,Alaska 99510 7.If perforating: 8.Well Name and Number: 77(8 What Regulation or Conservation Order governs well spacing in this pool? N/A CAL. Will planned perforations require a spacing exception? Yes ❑ No 0/ —ALF CD2-73 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0380075/ADL0387207/ADL0387212/FEE/ASRC • COLVILLE RIVER/ALPINE POOL• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effectiv a MD: Effectiv�pe th ND: MPSP(psi): Plugs(MD): Junk(MD): 21,810 7,328 e 913 NA NA NA Casing Length Size MD TVD Burst Collapse Structural NA NA NA NA NA NA Conductor 77 16 114 114 NA NA Surface 3621 10 3/4 3657 2384 NA NA Intermediate 3836 7 5/8 3870 2459 NA NA Production NA NA NA NA NA NA Liner NA NA NA NA NA NA Perforation Depth MD(ft): NI Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): / -°vptOI,'- NA 41/2 L-80 16520 Packers and SSSY/Typev°IPACKER=BAKER PREMIER PAKER Packers and SSSV MD(ft)and ND(ft): MD=16448 TVD=6941 12.Attachments: Proposal Summary 0 Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 0 ' 14.Estimated Date for 5/19/2017 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL Cl Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG 0• GSTOR 0 SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: ROGER WINTER Contact Name: Roger Winter/Roger Mouser Authorized Title: WI FIELD SUPERVISOR Contact Email: N1927(conocophillips.com 7019 Contact Phone: 659-7506 Authorized Signature: e t �4 ,A•-- Date: 5/12/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 1-T- ZOO Plug Integrity ❑ BOP Test❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: pZed i--0 cif 0 G v c t.711"--ep ti Post Initial Injection MIT Req'd? Yes ❑ No Ki'''-- RBDMS (,L MAY 2 4 2017 Spacing Exception Required? Yes ❑ No ' Subsequent Form Required: / — f0 4 / APPROVED BY Approved by: i P COMMISSIONER THE COMMISSION Date:5- iL (7 -/t /Iii Submit Form and Form 10-403 Revised 4/2017 0 iOeI' for'12 months from the date of approval. Attachments in Duplicate • • RECEIVED May 12, 2017 MAY X 5 2017 AOGCC Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 Dear Commissioner Cathy Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well CD2-73,PTD 206-196 for repairing surface casing leak. Please contact me at 907-659-7506 if you have any questions. Sincerely, ; Roger Winter ConocoPhillips Well Integrity Field Supervisor Enclosures: Description Summary of Proposal 10-403 Application for Sundry Approvals CD2-73 Wellbore Schematic • • ConocoPhillips Alaska,Inc. Alpine Well CD2-73 (PTD 206-196) SUNDRY NOTICE 10-403 APPROVAL REQUEST May, 2017 This application for Sundry approval for Alpine well CD3-73 is for the inspection and repair of surface casing with a suspected surface casing leak. Subsequent diagnostics indicate that the leak is relatively shallow. ConocoPhillips requests approval to inspect and repair the surface casing. With approval, inspection and repair of the surface casing will require the following general steps: 1. Secure the well as needed with mechanical plug in tubing 2. Remove the floor grate,well house, flow lines, and other equipment as necessary from around the wellhead. 3. Remove gravel around well head and excavate to 4. Install nitrogen purge equipment for the conductor and OA(if needed) so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary.Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine type of patch or repair needed to return the casing to operational integrity. 7. QA/QC will verify the repair for a final integrity check. 8. Perform a low-pressure test(Open OA shoe)to confirm no fluid to surface. 9. Install anti-corrosion coating as specified by CPAI Corrosion Engineer. 10. Replace the conductor and fill the void with cement and top off with sealant. 11. Backfill as needed with gravel around the wellhead. 12. Remove plug(s)and return the well to injection. 13. File 10-404 with the AOGCC post repair. `/* WNS INJ CD2-73 ConocoPhillips „ Well Attributes • Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status net(°) MD(ftKB) Act Btm(ftKB) C,b,,,,{'hll,tm 501032059000 ALPINE INJ 93.25 18,658.14 21,810.0 ° .-. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-CD2-73,7/7/20143:29:46 PM SSSV:WRDP Last WO: 44.85 8/14/2009 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:RESET A-1 INJ VLV hipshkf 7/7/2014 .............. ............................... Casing Strings Casing Description OD(in) ID(In) Top(MB) 'Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I-..Grade Top Thread Description ( ) (15.250p(ftKB) 114.0 114.0 62.50 H-40 Welded HANGER;31.4" -11f--'1,III .,Casing o FA eE OiInsulated OD(i)0 3/ ID 4 ID(I)950 To (ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread II 136.7 3,657.2 2,384.2 45.50 L-80 BTC-M k I � ) p( ) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread INTERMEDIATE- 75/8 6.875 34.8 3,870.2 2,459.9 29.70 L-80 BTCM UPPER I Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) 'Set Depth(TVD)...WVLen(I...Grade Top Thread INTERMEDIATE- 75/8 6.875 3,870.2 17,173.0 7,195.5 29.70 L-80 BTCM ......................................................... fx r .-.LOWER - I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND) WUL n(L..Grade Top Thread a+ OPEN HOLE 6.151 17,173.0 21,810.0 7,328.2 � a' Tubing Strings., �' Tubing Description String Me...ID lin) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection c I TUBING 41/2 3.958 31.4 16,520.8 6,967.6 12.60 L-80 IBTM Completion Details CONDUCTOR Insulated(48'); l o Nominal ID 37.0-114.0 Top(ftKB)) To p(TVD)(ftKB) Top Incl(°) Item Des Com (in) 31.4 31.4 0.00 HANGER TUBING HANGER 3.958 " 2,325.9 1,9102 67.93 NIPPLE CAMCO DB-6 NIPPLE 3.812 NIPPLE;2,325.9 VALVE;2,325,9 s Py 16,448.7 6,941.6 69.08 PACKER BAKER PREMIER PACKER 3.875 16,508.4 6,963.1 68.74 NIPPLE HES XN NIPPLE 3,725 16,519.4 6,967.1 68.68 WLEG UNIQUE MACHINE WIRELINE ENTRY GUIDE 3.875 ,i Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Inc! Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) ,.¢ 2,325.9 1,910.2 67.93 VALVE 3.81"A-1 INJECTION VALVE(HSS-172) 7/4/2014 1250 4Mandrel Inserts 1 St all C on Top(ND) Valve Latch Port Size TRO Run o SURFACE;36.7.3.657.2-.. - No Top(RHO) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date m 1 16,337.6 6,902.2 CAMCO KBG-2- 1 GAS LIFT DMY BK 0.000 0.0 9/24/2009 INTERMEDIATE-UPPER;34.8 R1 -3.670.2- Notes:General&Safety `j End Date Annotation 9/2/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9,0 (j 1 i GAS LIFT;16,337.6 I. X.: 1 ,( d •Vii. PACKER:16,448.7 s gCE ' 9 A NIPPLE;16.508.4 ,I& . 1 WLEG;16,519.4 INTERMEDIATE-LOWER; 3,870.0-17,173.0 OPEN HOLE;17,173.0-21,810.0 "°. • • Bettis, Patricia K (DOA) From: NSK Well Integrity Field Supv <N1927@conocophillips.com> Sent: Tuesday, May 16, 2017 3:27 PM To: Bettis, Patricia K (DOA) Subject: RE: CRU CD2-73 Yes that is the bottom of open hole. Please correct on the forms I sent you and I will correct originals. From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Tuesday, May 16, 2017 2:36 PM To: NSK Well Integrity Field Supv<N1927@conocophillips.com> Subject: [EXTERNAL]CRU CD2-73 Good afternoon Roger, On Form 10-403, Box 11. Present Well Condition Summary, it is stated that the effective depth of the well is 17,173' MD (7,195'TVD). On Form 10-403,Well Completion or Recompletion Report and Log, Box 23, it states that CRU CD2-73 has an open hole completion from 17,705-21810' MD (7,302-7,328'TVD). Please verify that the effective depth of the well is 21,810' MD. Thank you Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave.,Ste 100 Anchorage,AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Tuesday, May 16, 2017 2:36 PM To: NSK Well Integrity Field Supv Subject: CRU CD2-73 Good afternoon Roger, On Form 10-403, Box 11. Present Well Condition Summary, it is stated that the effective depth of the well is 17,173' MD (7,195'ND). On Form 10-403,Well Completion or Recompletion Report and Log, Box 23, it states that CRU CD2-73 has an open hole completion from 17,705-21810' MD(7,302-7,328'ND). Please verify that the effective depth of the well is 21,810' MD. Thank you Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Ste 100 Anchorage,AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • 410 Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Wednesday, May 3, 2017 8:23 AM To: Wallace, Chris D (DOA) Subject: CRU CD2-73 (PTD# 208-196) Attachments: CD2-73.pdf; CD2-73 90-day TlOjpg Chris— CD2-73 was reported for bubbling in the conductor. The well passed an MIT-IA to 2500 psi. DHD performed a surface casing leak detect, and there are indications the well has a shallow leak in the surface casing. The well will be shut-in as soon as possible. We will submit a 10-403 form for a repair when we identify a proposed solution. The well schematic and 90-day TIO is attached. Thanks, Travis Travis Smith/Rachel Kautz Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SOWED MAY 0 82017 1 • • t a U C es w C p rte U C z E E 0 C) z = LL ti r r N N a N III ! r o A B Q a W 'S • • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~('')Q - 1 `Z ~~ Well History File Identifier Organizing (done) RE CAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: :~.,~,a iuuiuuuuuui DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: BY: l Maria ~ __ Date: ' / /L Project Proofing BY: Maria _ Date: ~/ Scanning Preparation ~ x 30 = BY: Maria Date: ~ Production Scanning R,~a~~e~ed ummiAiiiiuu OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: h, m P + =TOTAL PAGES (Count does not include cover sheet) /s/ Stage 1 Page Count from Scanned File: 1 ~J I (Count does include cov r sheet) Pa a Count Matches Number in Scannin Preparation: _l~YES NO 9 g BY: Maria Date: ~~ /s/ ~ I_ ~9 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned III II'IIIIIIII ~IIII BY: Maria Date: /s/ Comments about this file: Quality Checked III II~III III IIII III 10/6/2005 Well History File Cover Page.doc • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, August 02, 2010 To: Jim Regg '~ v~b i~ P.I. Supervisor ~Q~Cl' ~ SUBJECT: Mechanical Integrity Tests tt CONOCOPHILLIPS ALASKA INC CD2-73 FROM: Jeff Jones COLVILLE RIV UNIT CD2-73 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J~F'L Comm Well Name: COLVILLE RIV UNIT CD2-73 Insp Num: mitJJ100802073911 Rel Insp Num: API Well Number: 50-103-20590-00-00 Permit Number: 208-196-0 Inspector Name: Jeff Jones Inspection Date: 6/12/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. WCII CD2-73. Type Inj. G TVD 6941 ~ IA ]686 2415 2405 2405 ' P.T.D 2081960 ~ TypeTest ! SPT Test psi 1735 ' ~ QA 350 435 430 430 Interval aYRTST per, P - Tubing 3430 3430 3430 3430 NOtes: 1.3 BBLS diesel pumped; no exceptions noted. -~ Monday, August 02, 2010 Page 1 of 1 DATA SUBMITTAL COMPLIANCE REPORT 7/8/2010 Permit to Drill 2081960 Well Name/No. COLVILLE RIV UNIT CD2-73 Operator CONOCOPHILLIPS ALASKA INC MD 21810 TVD 7328 Completion Date 8/13/2009 Completion Status WAGIN Current Status WAGIN API No. 50-103-20590-00-00 REQUIRED INFORMATION Mud log No Samples No Directional Survey es DATA INFORMATION Types Electric or Other Logs Run: GR/Res/PWD (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Etectr Data Digital Dataset Loa Loq Run Interval pH / Ty Med/Frmt Number Name Scale Media No Start Stop CH Received Comments pt LIS Verification 3634 21810 Open 9/1/2009 LIS Veri, RPD, RPM, RPS, RPX, FET, GR, ROP ED C Lis 18487dlnduction/Resistivity 3634 21810 Open 9/1/2009 LIS Veri,RPD, RPM, RPS, RPX, FET, GR, ROP og Induction/Resistivity 25 Col 114 17830 Open 9/1/2009 PB1 MD DGR, EWR o Induction/Resistivity 25 Col 114 17830 Open 9/1/2009 P61 TVD DGR, EWR pt LIS Verification 3634 17826 Open 9/1/2009 PB1 LIS Veri, RPD, RPM, RPS, RPX, FET, GR, ROP D C Lis 18488~duction/Resistivity 3634 17826 Open 9/1/2009 PB1 LIS Veri, RPD, RPM, RPS, RPX, FET, GR, ROP ~o Induction/Resistivity 25 Col 114 21810 Open 9/1/2009 MD DGR, EWR Log Induction/Resistivity 25 Col 114 21810 Open 9/1/2009 TVD DGR, EWR Lo / G~a ma Ray 2 Col 114 21810 Case 5/6/2010 BAT, GR D C 19612y^5ee Notes 0 0 Case 4/6/2010 GR logs in EMF and PDS graphcis Well Cores/Samples Information: r 1 L J ~ Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 7/8/2010 Permit to Drill 2081960 Well Name/No. COLVILLE RIV UNIT CD2-73 MD 21810 TVD 7328 ADDITIONAL INF ORMATION Well Cored? ~.~/L~~\'_ Chips Received? ~YTR" Analysis ~''-TN- Received? Completion Date 8/13/2009 Operator CONOCOPHILLIPS ALASKA INC Completion Status WAGIN Current Status WAGIN Daily History Received? ~~"'~ ~N~ Formation Tops L.L"'" API No. 50-103-20590-00-00 UIC Y Comments: Compliance Reviewed By: _ Date: ~~~~~_~ ~ ~ ~3A'T Sonic ~ ~ Page 1 of 2 Anderson, Nina M From: Schwartz, Guy L (DOA) [guy.schwartz@alaska.gov] Sent: Thursday, April 15, 2010 9:57 AM To: Anderson, Nina M Subject: FW: BAT Sonic ~~ ~ ~ ~p Nina, ~' ' List is below of what is not here. For injectors we need both hard copy and digital. V ~~OfO Guy Schwartz '' Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Mahnken, Christine R (DOA) Sent: Thursday, April 15, 2010 8:21 AM To: Schwartz, Guy L (DOA) Subject: RE: BAT Sonic ~ •,~_ - C02-121 No BA CD3-124 BAT is there CD4-24 BAT is there CD2-78 BAT is there ~~~~~~ ~z~ ao~-,9~ ~9~~a /~ ~// ~i~ ado-aka ~~p-~3~ ~~i~ It is on RBDMS under Logs or Data List to look for what we have and what I have put into it. From: Schwartz, Guy L (DOA) Sent: Wednesday, April 14, 2010 10:38 AM To: Mahnken, Christine R (DOA) Subject: FW: BAT Sonic Christine, Is this something that is easy to check??? I would still like hard copies... Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Anderson, Nina M [mailto:Nina.Anderson@conocophillips.com] Sent: Wednesday, April 14, 2010 10:30 AM To: Schwartz, Guy L (DOA) Subject: FW: BAT Sonic Guy - Can you please verify your records and see if you have hard copies of the BAT sonic data from the following injectors? If the data from any of these wells still needs to be updated, would you preferjust a log or also a CD? Thanks. 5/6/2010 BAT Sonic ~ • Page 2 of 2 Nina Anderson Drilling Engineer Alpine Drilling Team Office: (907)-265-6403 Cell: (907) 575-3256 Well Read Comments CD3-121 29-Mar-10 In Progress CD3-124 27-Feb-10 Sent to State CD4-24 23-Dec-09 CD2-78 -7-Sep-09 CD2-73 7-Aug-09 CD4-26 27-May-09 CD3-118 24-Mar-08 1 From our records it appears that CD2-02, CD2-11, CD2-4Q4, and 1J-127 Ll have no formal presentation, log with headers, and appear to be trial runs. 2 CD4-214, CD4-17, CD3-112, and CD4-209 have no remarks, simply a header and the logs. Vern Johnson requested that comments be made on the logs such as TOC and a bond quality Good versus Fair, etc. be made on the logs which are included from CD3-118 and newer. 5/6/2010 Guy - Included in this package are the BAT sonic cement log evaluations for CD3-121, CD3-123, and CD2-73. Please let me know if you need any further information. Thanks, Nina Anderson ConocoPhillips Alaska Alpine Drilling (907) 265-6503 MEMORANDUM TO: Jim Regg ~~~ r/(z-Z~ P.I. Supervisor FROM: RCN (~C~~C~) Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, November O5, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHII.LIPS ALASKA INC CD2-73 COLVILLE RIV iINIT CD2-73 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J~~=-' Comm Well Name: COLVILLE RIV UNIT CD2-73 API Well Number: 50-103-20590-00-00 Inspector Name: RCN lnsp Num: mitRCN091105104936 Permit Number: 208-196-0 Inspection Date: 10/19/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. - We^ I CD2-73 ''t`ype lnj. W TVD ~ 6941 ~ lA ~ 576 II -- P.T.D~ zo81960 ~ TypeTest SPT Test psi 24]5 QA ~ 295 ~ ~ L 2415 -~ - 406 - 2388 j 2385 T --- ~ 337 335 -- - - -`----'-- -- -- - ~-- --- - --- -- lnterVal INITAL P~F P - Tubing ~ 1348 -~-- ~ 1349 ~ 1349 1349 ~ _ Notes: i,~a:j ~r°«cv~e ~~.~ 1'1355; Thursday, November O5, 2009 Page 1 of 1 s • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg~alaska.gov; tom.maunder~afaska.gov;bob.tieckensteinlj>~ai~Ca.gov;doa.aogcc.prudhoe.bay~alaska.gov OPERATOR: ConocoPhilli~ Alaska Inc. FIELD 1 UNIT 1 PAD: Alpine / CRU f CD2-73 DATE: 10119/09 OPERATOR REP: Colee/Philiips AOGCG REP: Bob Noble Packer Pretest Initial 15 Min. 30 Min. Well CD2-73 T In'. W TVD 6,942' T ~ 1,348 . 1,348 1,349 1,349 Interval I P.T.D. 2081964 T test P Test 1736 576 2,415 2,388 2,385 P/F P Notes: Initial MITIA OA 295 `~ 337 335 Well T In'. TVD T ~ Interval P.T.D. T test Test Casi P!F Notes: OA Well T In'. TYD Tubi Interval P.T.D. T test Test Casi P/F Notes: OA Well T In". TVD T ~ Interval P.T.D. T test Test - PiF Notes: OA Well T In'. TVD Tutu. Interval P.T.D. T test Test P/F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes. M =Annulus P =Standard Pressure Test R = Internal Fiaxi'waetive Tracer Survey A = Tern Sunvey D = Temper~ure Tes# ~~ ~~ INTERVAL Codes I = Inital Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT CRU CD2-7310-19-09.x1s Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, September 29, 2009 8:24 AM To: 'Anderson, Nina M' Cc: 'Allsup-Drake, Sharon K' Subject: RE: CD2-73 (208-196) Nina and Sharon, Following up on our message trafFc ._. The PBTD listed on the 407 should be the deepest open depth of the particular well segment. In the case of CD2-73 it would be the drillers TD of 21810'. I will make the hand correction on the 407. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Friday, September 25, 2009 1:53 PM To: 'Anderson, Nina M' Cc: Allsup-Drake, Sharon K Subject: RE: CD2-73 (208-196) Nina and Sharon, Thanks for the info. I will get back to you regarding PBTD. The geologists are out today. Tom From: Anderson, Nina M [mailto:NinarAnderson@conocophillips.com] Sent: Thursday, September 24, 2009 5:03 PM To: Maunder, Thomas E (DOA) Cc: Allsup-Drake, Sharon K Subject: RE: CD2-73 (208-196) Tom -Please see below in regards to your questions. 1) The TWC is installed in the profile with the Landing jt. The rig tests the hanger seals from above the TWC to 5000 psi. They nipple up the tree and again test from above the TWC to 5000 psi. The casing below does not see the higher 5000 psi test pressures used for testing the hanger seats and tree. The next step was missing from the drilling time log which is pulling the TWC. After the TWC is pulled, the casing is then tested to 3500 psi. 2) ! have a copy of the original email where we proposed a 10 minute test instead of a 30 minute test on the casing. I will forward this email to you prompty. Reviewing a different wells procedure for returning to a temporarily suspended cased weN, we did indeed test that casing for 30 minutes. For any future requests, we will standardize the pressure #est at 30 minutes so there wiN not be any question. 3) I understand there might have been some confusion with the definition of PBTD. The deepest accessible point in the well, and the drillers TD for CD2-73 is 21,810' MD. Should this be the depth recorded for PBTD and do you want a corrected 407 submitted? 1 searched the AOGCC website although 1 was unable to find a PBTD definition. For clarification, can you please provide your definition of PBTD so that I can share this with the other drilling engineers. Please let me know if you have any further questions or comments. Thanks. 9/29/2009 Page 2 of 2 Nina Anderson Drilling Engineer Alpine Drilling Team Office: (907)-265-6403 Cell: (907) 575-3256 From: Maunder, Thomas E {DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, September 24, 2009 3:27 PM To: Anderson, Nina M Subject: CD2-73 (208-196) Nina, I am reviewing the 407 recently submitted for this well and have a couple of questions. 1. When preparations are being made to SD and move to CD3 after setting the surface casing, a TWC is run and it is stated that it was tested to 5000 psi. All o#her tests at that time are to 3500 psi. Is this a typo? 2. When operations are resumed, the casing test is only conducted for 10 minutes.. I thought we had exchanged messages that the test should be 30 minutes. 3. On the front of the 407, the PBTD (box 9) is given as the 7-5l8" casing shoe (17703'). Why was that chosen rather that the OH TD (21810')? Thanks in advance. Tom Maunder, PE AOGCC 9/29/2409 CD2-73 (PTD 208-196) ~ ~ Page 1 of 2 Maunder, Thomas E (DOA) From: Anderson, Nina M [Nina.Anderson@conocophillips.com] Sent: Thursday, September 24, 2009 5:07 PM To: Maunder, Thomas E (DOA) Subject: FW: CD2-73 (PTD 208-196) Tom - Below is the email correspondence in regards to testing the casing on CD2-73. From the email below, we had requested a 10 min test. Please let me know i# you have any further questions. Thanks. Nina Anderson Drilling Engineer Alpine Drilling Team Office: (907)-265-6403 Cell: (907) 575-3256 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, June 25, 2009 4:10 PM To: Anderson, Nina M Cc: Doyon 19 Company Man; McKeever, Steve Subject: RE: CD2-73 (PTD 208-196) Nina, Thanks for meeting. I am surprised as well that neither of us has a paper trail on this one. The likelihood of shutting down at a casing point was clearly stated in the permit application letter. !remember that in fact operations were SD sometime in January as you noted in our conversation. Your proposed work is appropriate for resuming operations. Although not stated, I presume that CPAI will continue drilling CD2-73 as presently permitted and that the Inspector will be notified regarding the BOP test. A copy of this message should be available on the rig. Call or message with any questions. Tom Maunder, PE AOGCC From: Anderson, Nina M [mailto:Nina.Anderson@conocophillips.com] Sent: Thursday, June 25, 2009 2:57 PM To: Maunder, Thomas E (DOA) Cc: Doyon 19 Company Man; McKeever, Steve Subject: CD2-73 (PTD 208-196) Tom - Doyon 19 will be moving on to CD2-73 next week around June 30~'. CD2-73 was temporarily shutdown with surface casing for CD3 ice road operations in January 2009. The 10-3/4" casing was cemented and pressure tested to 3500 psi for 30 minutes. The floats were checked following the plug being bumped. The wellbore currently contains a kill string to 2,046' MD. Please review the planned procedure below and let us know if this is acceptable. Thanks. 9/29/2009 CD2-73 (PTD 208-196) 1. Before moving on CD2-73, confirm that a BPV is installed. 2. Move on Doyon 19. 3. Rig up over CD2-73, dewater cellar as required. 4. Pull BPV. Circulate out diesel with 9.6 Brine. 5. Install two way check. 6. ND Tree. NU BOPE. Body test BOP and flange break. 7. Pull two way check. 8. Pressure test casing to 3500 psi for 10 minutes. 9. Pull tubing hanger to floor and stand back kill string. 10. Set test plug and test BOPE to 3500 psi. Nina Anderson Drilling Engineer Alpine Drilling Team Office: (907)-265-6403 Cell: (907) 575-3256 Page 2 of 2 9/29/2009 MEC:3ANICAL INTEGRITY REPORT rnrulus Pre s Test: _? 15 min JO m in s ` v.~t~v~ .~~`c ~ c C~ r ~ ~ 1 ~ -.d ~ ~- BUD u:..= : ~ ,'S © \ OPER ~ FIELD ~, ~•~sS ~~ ~J .G r ~~~r .,y . . ~~`t- ®~ i,~LL NUMBER ~\~`,~ ~~ ~~~~lS n ~ LL DAT ~ TD : ~ ~~5~~.?~.. ~`3~~ ~-vD ; ?BTD : ~~?m 'Z~~ o ~ VD Cas i_^g ~~l~ Shoe . 1~.'~~~ t-m ~TVD ; DV . ?~ =4~i .=:,e. • ~ ~ Shoe . `~ T`TD ; =CP . ?•~ _':J _~bi~V ~,~~~ Packer t~~t~*~ TVD; Set at ~~~~~ ole S_ce ~_ and ~ I Perks ~_ to ~ \CC: . ~`1, CCU S ~ ~` ~ l'~ ''_= C"r',~?~?C~?, TNTEGRITY - PART #? '-r' CHI N I C2_T., INTE GRl'T~' - PART # Z Cement Volumes :~ Amt. Liner Csg ~~~j`j1y; DV C 3®Z X ~ ` ` \ ~ Cr.t -rot to cover oers ~~ ~~ S ~~~Lti~-~`~ `~ ~~~M ,~ c~~ ~ _ _ _ =eoretical TOC c°_~~1Zp Y\ ~ ~ ~~,~ ~ CBL evaluation, gone above o~ c~ `~~~ ~5 fccT v.~v ~: (;4T S~~`rc Cement Bond Log (Yes or No) ~~ ~ . In AOGCC File Production Log: Tyve ~~ ~~ ~ CONC-LJSIONS: ?art #1: ~ ('~ Par l2. ~s~ erf s ~ ~C ~~"Y''(~ /ati Evaluation ~ ~ From: Schneider, Tim S. [mailto:Tim.S.Schneider@conocophillips.com] Sent: Tuesday, August 18, 2009 11:03 AM To: Maunder, Thomas E (DOA) Subject: BAT CMT Evaluation: CD2-73: API 50-103-20590-00 Tam, The Doyon 19 has completed the CD2-73 MWAG service injector in the Alpine "A" formation. The attached BAT file is for your review. We are currently completing the post rig slickline work. Formation tops are noted below: To TwDSS fv1D C-30 C-20 2722 4754 K-3 mkr 3786 X884 Basal K-3 39$3 8300 4{-2 Mkr 4011 8371 Basal K-2 4097 8622 Albian 97 Albian 96 H RZ 69 76 16682 Base HR 7048 16874 K-1 Mkr 71 Q8 17039 Ku aruk Fm 7187 17281 LCUA+rliluveach 7192 17299 AI ine D 7238 17585 AI ine G 7248 17675 UJU 7251 17705 B3 sand 725E 17781 AI ine A Sd 7265 17891 Tim 907-265-6859 ------------------------------------------------------------------------ Preliminary Results from BAT CMT Evaluation attached. TOC ~ 16,120' Apparent Fair Bond 16,110' to 16,590' Apparent Good Bond 16,590' to 17,150' Apparent Fair Bond 17150' to 17260' Apparent Good Bond 17260' to 17490' ~ Apparent Fair Bond 17490'to 17590' 0 0 M 17500 17600 CSG 17700 ~~ ~~ ~~ P DTC Casing Energy HB Waveform5 FHB Waveform microsec per ft M~ BAT HF STC BAT HB STC ~ 240 40 ft 240 40 240 40 0 0.5 600 1000 600 100 1 :240 microseconds microseconds SGRC CASING CASING 0 200 microsec per ft microsec per ft 240 40 240 40 apt CASING DTC DTC microsec per ft microsec per ft microsec per ft 240 40 240 40 240 40 HALLIBURTON® DIRECTIONAL SURVEY REPORT ConocoPhl~~s Alaska, Inc. CD2-73 CoIvA1e Rl~er North Sbpe Borough Alaska USA AK-MW-000637598 SURVEYS NOT VERIFIED VERSUS DEFINITIVE VERSION. Measured Vertical Vertical Depth Inclination Direction Depth Latitude Departure Section Dogleg (feet) (degrees) (degrees) (feet) (feet) (feet) (feet) (deg/100ft) 0.00 0.00 0.00 0.00 0.00 N 0.00E 0.00 T1E-IN 37.45 0.00 0.00 37.45 0.00 N 0.00E 0.00 0.00 84.00 0.18 359.87 84.00 0.07 N 0.00 W 0.07 0.39 178.00 0.40 0.00 178.00 0.54 N 0.00 W 0.48 0.24 268.00 0.58 0.81 288.00 1.33 N 0.01E 1.19 0.20 360.00 0.78 3.48 359.99 2.42 N 0.05E 2.15 0.22 452.00 1.06 334.39 451.98 3.81 N 0.28 W 3.55 0.58 543.00 2.89 308.36 542.92 5.99 N 2.44 W 6.46 2.19 636.00 4.97 309.83 635.70 10.03 N 7.37 W 12.25 2.24 728.00 7.38 310.24 727.16 16.40 N 14.95 W 21.29 2.62 820.00 9.94 313.29 818.10 25.66 N 25.24 W 34.13 2.83 ono we +~ m ~+c cc ano nw oc ~~ u oc wow we nn ~ ca STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~. 9a9~9 '7 f'~ r, WELL COMPLETION OR RECOMPLETION REPORT AND :L~('~~ ~-;~~r~~~~' '`~~ 1a. Well Status: Oil ^ Gas Plugged Abandoned Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG Q ~ Other ^ No. of Completions: 1b. Well Class: Development ^ Exploratory ^ Service ~ `~ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: August 13, 2009 ~ 12. Perm~Drill Number: 208-196 / 309-237 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: January 5, 2009 ~ 13. API Number: 50-103-20590-00 4a. Location of Well (Governmental Section): Surface: 3069' FSL, 2003' FEL, Sec. 2, T11N, R4E, UM 7. Date TD Reached: August 11, 2009 / 14. Well Name and Number: CD2-73 / Top of Productive Horizon: 2630' FSL, 558' FEL, Sec. 32, T12N, R4E, UM 8. KB (ft above MSL): 53' RKB Ground (ft MSL): 15.6' AMSL,/ 15. Field/Pool(s): Colville River Field Total Depth: 856' FSL, 2534' FWL, Sec. 29, T12N, R4E, UM 9. Plug Back Depth (MD + TVD): y1^~ ~~~~ ' MD / TVD ,, G, Y a~ Alpine Oil Pool 4b. Location of Well (State Base Plane Coordinates): ~ Surface: x- 371230 / y- 5974155.5 Zone- 4 10. Total Depth (MD + TVD): r . 21810' MD / 7328' TVD ~' 16. Property Resignat~n: ~ ADL 3soo75/, 387207, 387212, ASRCNf~ifL402 TPI: x- 356918 y- 5979255 Zone- 4 Total Depth: x- 354787 - 5982803 Zone- 4 11. SSSV Depth (MD + TVD): nipple @ 2325' MD / 1910' TVD 17. Land Use Permit: 380075 18. Directional Survey: Yes Q No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): approx. 1500' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/Res/PWD 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE TING CORD AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMEN RE PULLED 16" 62.5# H-40 37' 114' 37' 114' 24" 5.5 sx Portland Type III 10.75" 45.5# L-80 37' 3657' 37' 2384' 13.5" 596 sx Class G, 281 sx CI G 7.625" 29.7# L-80 37' 17705' 37' 7302' 9.875" 45o sx CI G, 280 sx CI G 23. Open to production or injection? Yes No / If Yes, list each 24. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" 16520' 16448' open hole completion from 17705'-21810' MD 7302'-7328' TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ri. Z"~ DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED cement plug @ 3465' 328 sx Class G (to abandon fish) 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) WAG injector -waiting to be brought on-line Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GASOIL RATIO Flow Tubing Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Conventional Core(s) Acquired? Yes No / Sidewall Cores Acquired? Yes No / If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE ~ ~COMPi_ETETIOI~ D r ilk IED ; Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE ' .~" Ems;, F. ~,k~ :~ ~ 2009 ~ ~~~ //~y Q~a` ~ ~~ 28. GEOLOGIC MARKERS (List all formations and marker countered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes Q No If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1575' 1500' needed, and submit detailed test information per 20 AAC 25.071. C-30 3722' 2407 C-20 4686' 2776' K-3 7750' 3839' K-2 8386' 4063' Nanuq 13201' 5782' K-1 17042' 7153' Kuparuk 17172' 7195' Alpine 17593' 7291' CD2-73PB7 17830' 7310' N/A Formation at total depth: Alpine 30. LIST OF ATTACHMENTS Summary of Daily Operations, directional survey, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Nina Anderson @ 265-6403 ~Of/ /Le /1/l Printed Name/^~ M. Cha ers Title: WNS Drilling Suaerintendent ~ ~4 ~ ~ O Signature .~I~^c ~ /H. G~sw~~~ Phone '~ s G , ~O Date INSTRUCTIONS Sharon AllsulrDrake @ 263-4612 General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 ConoctrPhiilips 1 -~~1. err,; WNS ~ CD2-73 W ell Attributes jMax Angle 8 MD TD _ Wellbore APUU WI Field Name _ _ Well Status Incl (°) MD (HKB) ( Act Btm (kKB) i 501032059000 'ALPINE (INJECTING 93.25 18,658.14 21.810.0 (Comment H2S (ppm) (Date iAn t ton End Date i,K6-Grd (tt) (Rig Rele: M SSSV: wRDP _ (Last WO: i. 44.85 I 8/141 -' 'Annotation (Depth (ftK8) (End Date Annotation (Last Mod By (End Dale ~' Last Tag ~ _ 1 (Rev Reason: New Well, Pull Plug, GLV C/O _ - Imosbor 1_ 9/2/2009 Casin Strin s Casing Description String 0... String ID ... Top (HKB) Set Depth (f... Set Depth (ND) ... String WL_'. String ..... String Top Thrd CONDUCTOR 16 15.250 37.0 114.0 114.0 '~ 62.50 ~ H-40 Welded Insula ted 48 ( ) g ~ion 9 Casin Descri Strin 0... Strin ID ... 9 To ftK6 P ( ) Set De ih f... P ( Set De th ND P ( ) ~~~ Strin Wt... 9 Strin (String Top Thrd 9 ~~~ ,SURFACE 103/4 9.950 36.7 3,657.2 2,3842 45.50 L-80 - BTC-M Casing Description String 0... ~ String ID ... Top (ttKB) Set Depth (i... Sat Depth (ND) ... String Wt... String ... String Top Thrd i iINTERMEIDATE- 75/8 6.875 34.8 3,870.2 2,458.5 29.70 L-80 BTCM (UPPER Casing Des ription String 0... String ID ... Top (ftK8) Set Depth (f... Set Depth (ND) ... String Wt._ Str ng ... String Top Thrd INTERMEDIATE - 7 5/8 6.875 3,8702 17,173.0 7.195.5 I 29.70 L-80 BTCM LOWER ~ ption S ~ I String ID ... To ) S D ~~~ D) ... Set D String wt... String ... String Top 7hrd 6.951 OPEN HOLE 17 173 .0 21 ,810 0 7P328.2 3,B7D-17,1]3 `" ~, OPEN HOLE, ~ ~ 17,173-2181D .. TO (CD2-73), _ _ - 21,810 ~ r ConocoPhillips(Alaska) Inc. Western North Slope CD2 Alpine Pad CD2-73 501032059000 ~. . , ~ - „ Definitive Survey Report 17 August, 2009 ~:~ F€ __ ~~ gperry C)rillrsg Services ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well CD2-73 .Project: Western North Slope TVD Reference: CD2-73 (15.6 + 37.45) @ 53.05ft(Doyon 19) Site: CD2 Alpine Pad MD Reference: CD2-73 (15.6 + 37.45) @ 53.05ft(Doyon 19) Weil: CD2-73 North'.Referenco: True Wellbore: CD2-73 ----"survey Calculation Method: Minimum Curvature ..Design: CD2-73 Database: CPAI EDM Production ~Wefl _ CD2-73 - I Well Position +E/ W 0.00 ft Ea ting9. 5 371,230.20 ft Loegitude: 151 ?Z' 41.450 W' Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 15.60ft Wellbore -CD2-73 _~ Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2007 7/25/2009 21.43 80.70 _ 57.614 J Design CD2-73 _. __ _-__ __ -- - -_- Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 3,609.53 i Vertical Section: Depth From (TVD) +N/S +E/-W Direction (ft) (ft) (}t} (°), 37.45 0.00 0.00 334.00 ~ Survey Program Date i From (ft) To (ft) Survey (WeUbor®) Toot Narne Description Survey Date 84.00 820.00 CD2-73P61 Gyro (CD2-73P61) GYD-GC-SS Gyrodata gyro single shots 1/5/2009 12: 902.46 1,137.95 CD2-73P61 MWD (CD2-73PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/5/2009 12: 1,200.00 1,295.00 CD2-73P61 Gyro (CD2-73P61) GYD-GC-SS Gyrodata gyro single shots 1/5/2009 12: 1,326.78 3,609.53 CD2-73PB1 MWD (CD2-73P61) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/5/2009 12: 3,724.00 21,743.07 CD2-73 MWD (CD2-73) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/25/2009 1: survey I Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Fasting DLS `Sec tion Ift) (~) ~ (~) (ft) (ftl (ft) Ift) (ft) (ft) (°/'100') (ft) Survey Tool Name 37.45 0.00 0.00 37.45 -15.60 0.00 0.00 5,974,155.46 371,230.20 0.00 0.00 UNDEFINED I 84.00 0.18 359.87 84.00 30.95 0.07 0.00 5,974,155.53 371,230.20 0.39 0.07 GYD-GC-SS (1) 176.00 0.40 0.00 176.00 122.95 0.54 0.00 5,974,156.00 371,230.21 0.24 0.48 GYD-GC-SS (1) 268.00 0.58 0.81 268.00 214.95 1.33 0.01 5,974,156.78 371,230.23 0.20 1.19 GYD-GC-SS (1) 360.00 0.78 3.48 359.99 306.94 2.42 0.05 5,974,157.87 371,230.29 0.2T 2.15 GYD-GC-SS (1) 452.00 1.06 334.39 451.98 398.93 3.81 -0.28 5,974,159.27 371,229.99 0.58 3.55 GYD-GC-SS (1) 543.00 2.89 308.36 542.92 489.87 5.99 -2.44 5,974,161.49 371,227.86 2.19 6.46 GYD-GC-SS (1) 636.00 4.97 309.83 635.70 582.65 10.03 -7.37 5,974,165.61 371,223.00 2.24 12.25 GYD-GC-SS (1) 728.00 7.38 310.24 727.16 674.11 16.40 -14.95 5,974,172.11 371,215.54 2.62 21.29 GYD-GC-SS (1) 820.00 9.94 313.29 818.10 765.05 25.66 -25.24 5,974,181.55 371,205.41 2.83 34.13 GYD-GC-SS (1) 8/17/2009 10:33:14AM Page 2 COMPASS 2003.16 Build 69 Company: Project: Site: Well: We)Ibore: Design: Survey ConocoPhillips(Alaska) Inc. Western North Slope CD2 Alpine Pad CD2-73 CD2-73 CD2-73 MD Inc Azi TVD TVDSS (ft) l°) l°I (ft) (ft) 502.46 12.07 315.86 899.04 345.95 947.40 13.98 313.72 942.82 889.77 1,042.91 17.48 313.78 1,034.74 987.69 1,137.95 20.70 314.36 1,724.54 1,071.49 1,200.00 23.25 310.65 1,182.08 1,129.03 7,295.00 27.24 306.11 1,268.00 1,214.95 7,326.78 28.29 305.59 1,296.72 1,243.07 1,372.72 30.04 304.01 1,336.24 1,283.19 1,422.51 32.71 301.67 1,378.74 1,325.69 1,470.81 36.03 298.37 1,418.61 1,365.56 1,576.95 38.25 297.62 1,455.39 1,402.34 7,563.78 40.34 297.13 1,491.63 1,438.58 1,672.89 42.43 297.00 1,528.47 1,475.42 1,660.61 44.85 296.66 1,563.00 1,509.95 1,707.95 46.62 295.97 1,596.04 1,542.99 1,757.29 48.34 293.26 1,629.39 1,576.34 1,803.36 50.27 292.28 1,659.43 1,606.38 1,852.02 53.02 291.51 1,689.62 1,636.57 1,898.72 55.19 292.06 1,717.00 1,663.95 1,944.50 57.38 291.19 1,742.41 1,689.36 1,993.83 59.32 290.65 1,768.30 1,715.25 2,041.49 61.43 289.45 1,791.85 1,738.80 2,088.45 62.93 288.76 1,813.77 1,760.72 2,134.07 64.50 287.53 1,833.97 1,780.92 2,183.71 65.82 287.72 7,854.82 1,801.77 2,231.30 67.19 287.22 1,873.80 1,820.75 2,278.62 67.18 286.72 1,892.15 7,839.10 2,373.77 68.68 286.59 1,927.90 1,874.85 2,468.04 68.75 285.88 1,962.12 1,909.07 2,563.23 69.47 287.26 1,996.06 7,943.01 2,657.28 69.28 286.68 2,029.19 1,976.14 2,752.77 68.81 286.31 2,063.34 2,010.29 2,847.79 69.55 287.19 2,097.11 2,044.06 2,942.96 70.25 287.87 2,129.82 2,076.77 3,037.69 67.44 288.14 2,164.00 2,110.95 3,133.32 68.23 287.98 2,200.08 2,147.03 3,228.85 69.57 287.17 2,234.47 2,181.42 3,323.77 69.75 287.48 2,267.47 2,214.42 3,419.04 68.89 287.65 2,307.11 2,248.06 3,514.42 69.52 286.57 2,334.97 2,281.92 • ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: Well CD2-73 ND Referenc®: CD2-73 (15.6 + 37.45) @ 53.05ft(Doyon 19) MA R®ference: CD2-73 (15.6 + 37.45) @ 53.05ft (Doyon 19) North Reference: True Survey Calculation Method: Minimum Curvature Datat~ase: CPAI EDM Production i Map Map Vertical +NI-S +E/-W Northing Easting DLS Section (ft) (ft) (ft) (ft) ( °1100') (ft) Survey Tool Name 36.73 -36.42 5,974,192.00 .°,71,194.41 3.65 48.98 MWD+IFR-AK-CAZ-SC (3) 43.85 -43.62 5,974,200.05 371,187.34 4.38 58.54 MWD+IFR-AK-CAZ-SC (2) 61.65 -62.42 5,974,218.16 377,168.85 3.67 82.77 MWD+IFR-AK-CAZ-SC (2) 83.17 -84.85 5,974,240.06 371,746.80 3.41 111.94 MWD+IFR-AK-CAZ-SC (2) 98.81 -101.98 5,974,256.00 371,129.94 4:68 133.52 GYD-GC-SS (3) 123.85 -133.79 5,974,281.58 371,098.57 4.67 169.97 GYD-GC-SS (3) 132.52 -145.79 5,974,290.45 371,086.72 3.39 183.02 MWD+IFR-AK-CAZ-SC (4) 145.29 -164.18 5,974,303.54 371,068.56 4.16 202.56 MWD+IFR-AK-CAZ-SC (4) 159.32 -185.97 5,974,317.93 371,047.01 5.92 224.72 MWD+IFR-AK-CAZ-SC (4) 172.91 -209.59 5,974,331.93 371,023.63 7.85 247.29 MWD+IFR-AK-CAZ-SC (4) 185.98 -234.19 5,974,345.42 370,999.26 4.91 269.82 MWD+IFR-AK-CAZ-SC (4) 199.62 -260.53 5,974,359.50 370,973.16 4.51 293.62 MWD+IFR-AK-CAZ-SC (4) 214.39 -289.44 5,974,374.77 370,944.51 4.26 319.57 MWD+IFR-AK-CAZ-SC (4) 229.25 -318.82 5,974,390.13 370,915.39 5.10 345.81 MWD+IFR-AK-CAZ-SC (4) 244.27 -349.21 5,974,405.67 370,885.26 3.88 372.64 MWD+IFR-AK-CAZ-SC (4) 259.41 -382.27 5,974,421.37 370,852.47 5.34 400.73 MWD+IFR-AK-CAZ-SC (4) 272.92 -414.48 5,974,435.43 370,820.50 4.49 427.00 MWD+IFR-AK-CAZ-SC (4) 287.15 -449.88 5,974,450.26 370,785.35 5.79 455.30 MWD+IFR-AK-CAZ-SC (4) 301.19 -485.01 5,974,464.90 370,750.48 4.74 483.32 MWD+IFR-AK-CAZ-SC (4) 315.22 -520.41 5,974,479.54 370,715.33 5.04 511.44 MWD+IFR-AK-CAZ-SC (4) 330.21 -559.63 5,974,495.20 370,676.37 4.04 542.11 MWD+IFR-AK-CAZ-SC (4) 344.41 -598.55 5,974,510.06 370,637.70 4.94 571.94 MWD+IFR-AK-CAZ-SC (4) 358.00 -637.79 5,974,524.32 370,598.70 3.45 601.35 MWD+IFR-AK-CAZ-SC (4) 370.73 -676.66 5,974,537.72 370,560.06 4.21 629.84 MWD+IFR-AK-CAZ-SC (4) 384.37 -719.59 5,974,552.10 370,517.38 2.68 660.92 MWD+IFR-AK-CAZ-SC (4) 397.47 -761.22 5,974,565.91 370,475.98 3.04 690.94 MWD+IFR-AK-CAZ-SC (4) 410.20 -802.94 5,974,579.35 370,434.49 0.97 720.67 MWD+IFR-AK-CAZ-SC (4) 435.47 -887.41 5,974,606.07 370,350.47 1.58 780.42 MWD+IFR-AK-CAZ-SC (4) 460.03 -971.75 5,974,632.07 370,266.57 0.71 839.46 MWD+IFR-AK-CAZ-SC (4) 485.40 -1,056.99 5,974,658.89 370,181.79 1.55 899.62 MWD+IFR-AK-CAZ-SC (4) 511.09 -1,141.18 5,974,686.02 370,098.06 0.61 959.62 MWD+IFR-AK-CAZ-SC (4) 536.41 -1,226.68 5,974,712.81 370,013.01 0.61 1,019.86 MWD+IFR-AK-CAZ-SC (4) 562.00 -1,311.72 5,974,739.86 369,928.43 1.16 1,080.15 MWD+IFR-AK-CAZ-SC (4) 588.88 -1,396.96 5,974,768.19 369,843.67 0.96 1,141.67 MWD+IFR-AK-CAZ-SC (4) 616.14 -1,480.99 5,974,796.89 369,760.13 2.98 1,203.00 MWD+IFR-AK-CAZ-SC (4) 643.59 -1,565.19 5,974,825.78 369,676.42 0.84 1,264.59 MWD+IFR-AK-CAZ-SC (4) 670.46 -1,650.16 5,974,854.10 369,591.93 1.64 1,325.99 MWD+IFR-AK-CAZ-SC (4) 696.92 -1,735.14 5,974,882.01 369,507.42 0.41 1,387.02 MWD+IFR-AK-CAZ-SC (4) 723.81 -1,820.11 5,974,910.36 369,422.93 0.92 1,448.45 MWD+IFR-AK-CAZ-SC (4) 750.05 -1,905.33 5,974,938.05 369,338.18 1.25 1,509.38 MWD+IFR-AK-CAZ-SC (4) 8/17/2009 10:33:14AM Page 3 COMPASS 2003.16 Build 69 ~ r ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference- `JVell CD2-73 Project: Western North Slope TVb Ref®rence: CD2-73 (15.6 + 37.45) @ 53.05ft (Doyon 19) Sita: CD2 Alpine Pad MD Reference: CD2-73 (15.6 + 37.45) @ 53.05ft(Doyon 19) Well: CD2-73 North Reference: True W®Ilbore: CD2-73 Survey Calculation Method: Minimum Curvature Design: CD2-73 Database: CPAI EDM Production Survey MD Inc (ft) (°) 3,609.53 69.98 3,724.00 70.07 3,788.72 68.65 3,850.22 68.20 3,945.87 67.81 Azi 287.05 288.43 289.61 290.73 292.50 4,041.36 68.99 4,136.23 68.20 4,232.00 67.60 4,327.55 66.83 4,423.00 66.61 4,518.12 66.07 4,613.58 65.72 4,708.81 65.44 4,803.56 67.49 4,898.81 69.21 4,993.88 70.26 5,088.65 70.26 5,184.73 70.13 5,279.39 69.85 5,374.31 70.63 5,469.92 71.24 5,564.61 71.50 5,660.05 70.76 5,755.23 71.03 5,850.28 70.57 5,945.47 70.84 6,040.54 70.90 6,135.82 71.16 6,230.88 70.38 6,326.01 69.08 6,420.78 68.16 6,516.26 68.41 6,608.42 68.59 6,706.69 69.27 6,802.17 68.73 6,897.46 69.32 6,992.53 69.28 7,087.26 69.15 7,182.25 69.09 7,277.34 69.39 293.82 294.03 294.17 294.80 294.89 294.63 294.65 294.89 295.26 295.15 294.07 293.11 292.45 292.29 291.77 290.59 289.09 287.28 286.75 286.58 286.14 285.76 285.08 284.11 283.99 284.29 285.63 286.48 286.54 286.08 TVD (ft) 2,367.89 2,407.00 2,429.81 2,452.43 2,488.25 2, 523.41 2,558.03 2, 594.06 2,631.06 2,668.79 2,706.96 2,745.95 2,785.32 2,823.15 2,858.29 2, 891.22 2,923.23 2,955.78 2,988.17 3,020.27 3,051.50 3,081.75 3,112.62 3,143.77 3,175.03 3,206.48 3,237.64 3,268.61 3,299.92 3,332.88 3,367.43 3,402.75 3,436.53 3,471.86 3,506.08 TVDSS (ft) 2,314.04 2,353.95 2,376.76 2,399.38 2,435.20 2,470.36 2,504.98 2,541.01 2,578.01 2,615.74 2,653.91 2,692.90 2,732.27 2,770.10 2,805.24 2,838.17 2,870.18 2,902.73 2,935.12 2,967.22 2,998.45 3,028.70 3,059.57 3,090.72 3,121.98 3,153.43 3,184.59 3,215.56 3,246.87 3,279.83 3,314.38 3,349.70 3,383.48 3,418.81 3,453.03 +NI-S (ft) 775.85 808.63 828.37 848.09 880.75 915.67 951.49 987.72 t ,024.23 1,061.07 1,097.56 1,133.89 1,170.22 1,207.04 1,244.73 1,281.87 1,317.57 1,352.57 1,386.42 1,419.93 1,452.57 1,483.02 1,511.21 1,537.53 1,563.27 1,588.58 1,613.26 1,637.22 1,659.83 1,681.50 1,703.06 1,725.95 1,749.67 1,775.73 1,800.76 285.46 3,540.19 3,487.14 1,824.94 284.99 3,573.79 3,520.74 1,848.30 285.15 3,607.41 3,554.36 1,871.32 285.30 3,641.26 3,588.21 1,894.63 285.09 3,674.97 3,621.92 1,917.94 Map +E/-W Northing (ft- (ft) -1,990.75 5,974,965.32 -2,093.22 5,974,999.85 -2,150.47 5,975,020.56 -2,204.16 5,975,041.20 -2,286.60 5,975,075.27 -2,368.23 5,975,111.59 -2,448.96 5,975,148.78 -2,529.96 5,975,186.40 -2,610.13 5,975,224.28 -2,689.70 5,975,262.47 -2, 768.81 5,975,300.31 -2, 848.01 5, 975, 337.99 -2,926.75 5,975,375.67 -3,005.42 5,975,413.82 -3,085.52 5,975,452.89 -3,166.60 5,975,491.41 -3,248.35 5,975,528.50 -3,331.69 5,975,564.93 -3,413.95 5,975,600.18 -3,496.75 5,975,635.10 -3, 581.01 5, 975, 669.19 -3, 665.41 5, 975, 701.08 -3, 751.21 5, 975, 730.73 -3, 837.21 5, 975, 758.52 -3,923.20 5,975,785.74 -4,009.41 5,975, 812.52 -4,095.77 5,975,838.67 -4,182.63 5,975,864.12 -4,269.49 5,975,888.22 -4,356.05 5,975,911.37 -4,441.63 5,975,934.39 -4,527.32 5,975,958.76 -4,609.72 5,975,983.88 -4,697.64 5,976,011.44 -4,783.19 5,976,037.94 -4,868.82 5,976,063.58 -4,954.63 5,976,088.41 -5,040.15 5,976,112.90 -5,125.79 5,976,137.67 -5,211.59 5,976,162.44 Map Vertical Fasting DLS Section (ft) ( °l100'). (ft) Survey Tool Name 369,253.23 0.68 1,570.02 MWD+IFR-Hh-GAZ-SC ~4) 369,151.35 1.14 1,644.40 MWD+IFR-AK-CAZ-SC (5) 369,094.44 2.78 1,687.24 MWD+IFR-AK-CAZ-SC (5) 369,041.11 1.84 1,728.49 MWD+IFR-AK-CAZ-SC (5) 368,959.24 1.76 1,794.00 MWD+IFR-AK-CAZ-SC (5) 368,878.24 1.78 1,861.16 MWD+IFR-AK-CAZ-SC (5) 368,798.13 0.66 1,928.75 MWD+IFR-AK-CAZ-SC (5) 368,717.78 0.64 1,996.82 MWD+IFR-AK-CAZ-SC (5) 368,638.25 1.01 2,064.78 MWD+IFR-AK-CAZ-SC (5) 368,559.34 0.25 2,132.77 MWD+IFR-AK-CAZ-SC (5) 368,480.87 0.62 2,200.25 MWD+IFR-AK-CAZ-SC (5) 368,402.31 0.37 2,267.62 MWD+IFR-AK-CAZ-SC (5) 368,324.22 0.37 2,334.79 MWD+IFR-AK-CAZ-SC (5) 368,246.19 2.19 2,402.37 MWD+IFR-AK-CAZ-SC (5) 368,166.76 1.81 2,471.36 MWD+IFR-AK-CAZ-SC (5) 368,086.33 1.53 2,540.29 MWD+IFR-AK-CAZ-SC (5) 368,005.22 0.95 2,608.20 MWD+IFR-AK-CAZ-SC (5) 367,922.49 0.66 2,676.20 MWD+IFR-AK-CAZ-SC (5) 367,840.84 0.34 2,742.68 MWD+IFR-AK-CAZ-SC (5) 367,758.63 0.97 2,809.10 MWD+IFR-AK-CAZ-SC (5) 367,674.95 1.33 2,875.38 MWD+IFR-AK-CAZ-SC (5) 367,591.09 1.53 2,939.75 MWD+IFR-AK-CAZ-SC (5) 367,505.80 1.95 3,002.69 MWD+IFR-AK-CAZ-SC (5) 367,420.27 0.60 3,064.04 MWD+IFR-AK-CAZ-SC (5) 367,334.74 0.51 3,124.88 MWD+IFR-AK-CAZ-SC (5) 367,248.99 0.52 3,185.41 MWD+IFR-AK-CAZ-SC (5) 367,163.07 0.38 3,245.45 MWD+IFR-AK-CAZ-SC (5) 367,076.64 0.73 3,305.06 MWD+IFR-AK-CAZ-SC (5) 366,990.19 1.27 3,363.47 MWD+IFR-AK-CAZ-SC (5) 366,904.02 1.37 3,420.89 MWD+IFR-AK-CAZ-SC (5) 366,818.83 1.01 3,477.78 MWD+IFR-AK-CAZ-SC (5) 366,733.55 1.33 3,535.93 MWD+IFR-AK-CAZ-SC (5) 366,651.57 0.88 3,593.36 MWD+IFR-AK-CAZ-SC (5) 366,564.12 0.69 3,655.33 MWD+IFR-AK-CAZ-SC (5) 366,479.02 0.72 3,715.33 MWD+IFR-AK-CAZ-SC (5) I 366,393.83 0.87 3,774.60 MWD+IFR-AK-CAZ-SC (5) 366,308.44 0.46 3,833.20 MWD+IFR-AK-CAZ-SC (5) 366,223.34 0.21 3,891.39 MWD+IFR-AK-CAZ-SC (5) 366,138.12 0.16 3,949.88 MWD+IFR-AK-CAZ-SC (5) 366,052.73 0.38 4,008.44 MWD+IFR-AK-CAZ-SC (5) 8/17/2009 10.33:14AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips Definitive Surrey Report Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD2 Alpine Pad Well: CD2-73 Wellbore: CD2-73 Design: CD2-73 Survey MD Inc Azi TVD TVDSS +NI-S (ft) (°) (°) (ft) (ft) (ft) 7,371.71 69.26 285.81 3,708.29 3,655.24 1,9x1.46 7,467.40 69.67 285.79 3,741.85 3,688.80 1,965.85 7,562.00 69.85 285.53 3,774.58 3,721.53 1,989.81 7,657.59 69.99 285.58 3,807.40 3,754.35 2,013.89 7,752.17 69.77 285.15 3,839.93 3,786.88 2,037.42 7,846.84 69.25 285.22 3,873.07 3,820.02 2,060.65 7,941.55 69.20 285.86 3,906.67 3,853.62 2,084.37 8,036.43 69.32 286.18 3,940.27 3,887.22 2,108.86 8,131.41 69.06 286.54 3,974.01 3,920.96 2,133.87 8,226.47 69.47 287.04 4,007.67 3,954.62 2,159.55 8,321.72 69.50 287.71 4,041.05 3,988.00 2,186.19 8,417.27 69.64 287.19 4,074.40 4,021.35 2,213.04 8,512.51 69.40 287.19 4,107.72 4,054.67 2,239.41 8,607.38 69.08 287.61 4,141.35 4,088.30 2,265.93 8,702.52 69.46 287.94 4,175.03 4,121.98 2,293.10 8,797.39 68.95 287.10 4,208.71 4,155.66 2,319.80 8,892.07 69.47 287.04 4,242.31 4,189.26 2,345.78 8,987.13 69.26 286.89 4,275.81 4,222.76 2,371.74 9,082.40 69.19 287.55 4,309.61 4,256.56 2,398.11 9,177.67 69.52 287.20 4,343.20 4,290.15 2,424.73 9,272.33 69.38 286.94 4,376.42 4,323.37 2,450.75 9,367.15 69.34 287.27 4,409.85 4,356.80 2,476.85 9,462.77 69.20 287.15 4,443.69 4,390.64 2,503.31 9,557.75 69.46 287.41 4,477.22 4,424.17 2,529.71 9,652.88 68.87 287.17 4,511.06 4,458.01 2,556.13 9,747.69 69.21 286.97 4,544.97 4,491.92 2,582.12 9,840.54 68.71 287.03 4,578.31 4,525.26 2,607.46 9,938.03 68.93 287.43 4,613.53 4,560.48 2,634.38 10,033.71 68.68 286.90 4,648.12 4,595.07 2,660.71 10,128.56 69.04 286.57 4,682.33 4,629.28 2,686.18 10,224.22 69.20 286.09 4,716.42 4,663.37 2,711.31 10,318.52 69.17 286.54 4,749.93 4,696.88 2,736.08 10,414.08 69.15 287.88 4,783.93 4,730.88 2,762.50 10,509.15 69.13 288.60 4,817.78 4,764.73 2,790.30 10,604.15 69.59 288.93 4,851.27 4,798.22 2,818.90 10,699.26 69.28 288.77 4,884.68 4,831.63 2,847.67 10,794.45 68.87 288.41 4,918.68 4,865.63 2,876.02 10,889.39 69.26 287.59 4,952.60 4,899.55 2,903.42 10,984.80 68.74 287.53 4,986.79 4,933.74 2,930.29 11,079.17 68.55 287.66 5,021.16 4,968.11 2,956.86 Local Co-ordinate Reference: Well CD2-73 TYD Referertee: CD2-73 (15.6 + 37.45) @ 53.05ft(Doyon 19) MD Reference: CD2-73 (15.6 + 37.45) @ 53.05ft(Doyon 19) North Reference: True Survey Calculation Method: Minimum Curvature Database: CPAI EDM Production Map +E/-W Northing (ft) (ft) -5,296.69 5,576,187.42 -5,382.92 5,976,213.29 -5,468.38 5,976,238.71 -5,554.87 5,976,264.27 -5,640.51 5,976, 289.27 -5,726.09 5,976,313.96 -5, 811.41 5 , 976, 339.14 -5,896.69 5,976,365.09 -5,981.88 5,976,391.55 -6,066.99 5,976,418.69 -6,152.13 5,976,446.78 -6,237.55 5,976,475.10 -6,322.78 5,976,502.92 -6,407.43 5,976,530.90 -6,492.17 5,976,559.51 -6,576.74 5,976,587.66 -6,661.36 5,976,615.08 -6,746.45 5,976,642.50 -6,831.53 5,976,670.32 -6,916.61 5, 976,698.40 -7,001.34 5,976,725.87 -7,086.15 5,976,753.42 -7,171.58 5,976,781.34 -7,256.43 5,976,809.19 -7,341.32 5,976,837.06 -7,425.96 5,976,864.50 -7,508.83 5,976,891.25 -7,595.66 5,976,919.66 -7,680.89 5,976,947.45 -7, 765.61 5, 976, 974.37 -7,851.38 5,977,000.97 -7,935.98 5,977,027.18 -8,021.29 5,977,055.06 -8,105.66 5,977,084.31 -8,189.84 5,977,114.34 -8,274.11 5,977,144.56 -8,358.38 5,977,174.34 -8,442.71 5, 977,203.18 -8,527.64 5,977,231.51 -8, 611.41 5 , 977, 2 59.51 Map Vertical Fasting DLS Section (ft) ( °1100') (ft) Survey Tool Name 365,968.05 0.73 4,066.&'9 MWD+IFR-AK-CAZ-SC (5/ 365,882.27 0.43 4,126.61 MWD+IFR-AK-CAZ-SC (5) 365,797.24 0.32 4,185.61 MWD+IFR-AK-CAZ-SC (5) 365,711.18 0.15 4,245.17 MWD+IFR-AK-CAZ-SC (5) 365,625.97 0.49 4,303.86 MWD+IFR-AK-CAZ-SC (5) 365,540.80 0.55 4,362.25 MWD+IFR-AK-CAZ-SC (5) 365,455.91 0.63 4,420.97 MWD+IFR-AK-CAZ-SC (5) 365,371.07 0.34 4,480.37 MWD+IFR-AK-CAZ-SC (5) 365,286.33 0.45 4,540.19 MWD+IFR-AK-CAZ-SC (5) 365,201.68 0.65 4,600.58 MWD+IFR-AK-CAZ-SC (5) 365,117.02 0.66 4,661.85 MWD+IFR-AK-CAZ-SC (5) 365,032.08 0.53 4,723.43 MWD+IFR-AK-CAZ-SC (5) 364,947.31 0.25 4,784.49 MWD+IFR-AK-CAZ-SC (5) 364,863.14 0.53 4,845.44 MWD+IFR-AK-CAZ-SC (5) 364,778.89 0.51 4,907.00 MWD+IFR-AK-CAZ-SC (5) 364,694.80 0.99 4,968.07 MWD+IFR-AK-CAZ-SC (5) 364,610.65 0.55 5,028.52 MWD+IFR-AK-CAZ-SC (5) 364,526.02 0.27 5,089.15 MWD+IFR-AK-CAZ-SC (5) 364,441.41 0.65 5,150.15 MWD+IFR-AK-CAZ-SC (5) 364,356.80 0.49 5,211.38 MWD+IFR-AK-CAZ-SC (5) 364,272.54 0.30 5,271.91 MWD+IFR-AK-CAZ-SC (5) 364,188.20 0.33 5,332.54 MWD+IFR-AK-CAZ-SC (5) 364,103.25 0.19 5,393.77 MWD+IFR-AK-CAZ-SC (5) 364,018.86 0.37 5,454.70 MWD+IFR-AK-CAZ-SC (5) 363,934.45 0.66 5,515.66 MWD+IFR-AK-CAZ-SC (5) 363,850.28 0.41 5,576.12 MWD+IFR-AK-CAZ-SC (5) 363,767.86 0.54 5,635.22 MWD+IFR-AK-CAZ-SC (5) 363,681.51 0.44 5,697.48 MWD+IFR-AK-CAZ-SC (5) 363,596.75 0.58 5,758.51 MWD+IFR-AK-CAZ-SC (5) 363,512.49 0.50 5,818.55 MWD+IFR-AK-CAZ-SC (5) 363,427.17 0.50 5,878.73 MWD+IFR-AK-CAZ-SC (5) 363,343.02 0.45 5,938.07 MWD+IFR-AK-CAZ-SC (5) 363,258.18 1.31 5,999.22 MWD+IFR-AK-CAZ-SC (5) 363,174.31 0.71 6,061.20 MWD+IFR-AK-CAZ-SC (5) 363,090.64 0.58 6,123.80 MWD+IFR-AK-CAZ-SC (5) 363,006.88 0.36 6,186.60 MWD+IFR-AK-CAZ-SC (5) 362,923.11 0.56 6,249.02 MWD+IFR-AK-CAZ-SC (5) 362,839.27 0.91 6,310.62 MWD+IFR-AK-CAZ-SC (5) 362,754.83 0.55 6,372.00 MWD+IFR-AK-CAZ-SC (5) 362,671.53 0.24 6,432.60 MWD+IFR-AK-CAZ-SC (5) 8/17/2009 10:33:14AM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-o rdinate Reference: Well CD2-73 Proyect: Western North Slope ND Ref®rence: CD2-73 (15.6 + 37.45) @ 53.05ft(Doyon 19) Site: CD2 Alpine Pad MD Reference: CD2-73 (15.6 + 37.45) @ 53.05ft(Doyon 19) Well: CD2-73 North Refe rence: True Wellbore: CD2- 73 Survey Cal culation Meth od: Minimum Curvature Design: CD2-73 Database: CPA I EDM Production - __ - I Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-5 +E/-W Northing Fasting;. DLS Section (ft) (°) (~) lft) (ft) (ft) (ft) (ft) (ft) ''' (°1100') (ft) Survey Tool Name 11,114.63 65.21 281.14 5,055.51 5,002.4b 2,983.49 -8,696.40 5,977,287.60 362,587.01 0.91 6,493.80 MWD+IFR-AK-CAZ-SG (5) 11,269.57 69.92 286.10 5,088.61 5,035.56 3,008.94 -8,781.67 5,977,314.50 362,502.21 1.23 6,554.05 MWD+IFR-AK-CAZ-SC (5) 11,364.95 69.44 285.02 5,121.73 5,068.68 3,032.94 -8,867.83 5,977,339.97 362,416.47 1.18 6,613.39 MWD+IFR-AK-CAZ-SC (5) 11,460.08 69.15 285.17 5,155.37 5,102.32 3,056.11 -8,953.75 5,977,364.61 362,330.98 0.34 6,671.88 MWD+IFR-AK-CAZ-SC (5) i 11,555.02 68.48 285.79 5,189.67 5,136.62 3,079.74 -9,039.06 5,977,389.70 362,246.09 0.93 6,730.51 MWD+IFR-AK-CAZ-SC (5) 11,650.24 69.00 285.95 5,224.20 5,171.15 3,104.00 -9,124.42 5,977,415.43 362,161.17 0.57 6,789.74 MWD+IFR-AK-CAZ-SC (5) 11,745.34 68.98 285.21 5,258.30 5,205.25 3,127.85 -9,209.93 5,977,440.73 362,076.08 0.73 6,848.66 MWD+IFR-AK-CAZ-SC (5) 11,840.54 69.00 284.56 5,292.43 5,239.38 3,150.68 -9,295.82 5,977,465.03 361,990.61 0.64 6,906.83 MWD+IFR-AK-CAZ-SC (5) 11,935.80 68.08 283.39 5,327.28 5,274.23 3,172.09 -9,381.85 5,977,487.92 361,904.97 1.50 6,963.79 MWD+IFR-AK-CAZ-SC (5) 12,031.08 68.15 283.22 5,362.80 5,309.75 3,192.44 -9,467.89 5,977,509.74 361,819.29 0.18 7,019.79 MWD+IFR-AK-CAZ-SC (5) 12,126.21 68.66 284.10 5,397.81 5,344.76 3,213.33 -9,553.84 5,977,532.10 361,733.72 1.01 7,076.24 MWD+IFR-AK-CAZ-SC (5) 12,221.32 68.47 284.77 5,432.57 5,379.52 3,235.39 -9,639.57 5,977,555.63 361,648.39 0.69 7,133.66 MWD+IFR-AK-CAZ-SC (5) 12,316.97 68.95 285.32 5,467.30 5,414.25 3,258.53 -9,725.64 5,977,580.24 361,562.74 0.73 7,192.19 MWD+IFR-AK-CAZ-SC (5) 12,412.11. 69.01 285.77 5,501.42 5,448.37 3,282.33 -9,811.20 5,977,605.50 361,477.60 0.45 7,251.08 MWD+IFR-AK-CAZ-SC (5) 12,506.98 69.15 286.82 5,535.30 5,482.25 3,307.19 -9,896.25 5,977,631.82 361,393.00 1.04 7,310.72 MWD+IFR-AK-CAZ-SC (5) ~ 12,601.48 68.90 287.16 5,569.13 5,516.08 3,332.98 -9,980.64 5,977,659.05 361,309.07 0.43 7,370.88 MWD+IFR-AK-CAZ-SC (5) ~ 12,696.70 69.40 288.26 5,603.02 5,549.97 3,360.05 -10,065.41 5,977,687.57 361,224.79 1.20 7,432.37 MWD+IFR-AK-CAZ-SC (5) i 12,792.12 69.41 289.30 5,636.58 5,583.53 3,388.80 -10,149.97 5,977,717.77 361,140.74 1.02 7,495.29 MWD+IFR-AK-CAZ-SC (5) li 12,887.15 68.91 289.30 5,670.39 5,617.34 3,478.16 -10,233.79 5,977,748.56 361,057.44 0.53 7,558.42 MWD+IFR-AK-CAZ-SC (5) 12,982.18 69.64 289.31 5,704.02 5,650.97 3,447.54 -10,317.67 5,977,779.37 360,974.08 0.77 7,621.60 MWD+IFR-AK-CAZ-SC (5) 13,077.86 69.12 289.48 5,737.72 5,684.67 3,477.28 -10,402.14 5,977,810.55 360,890.14 0.57 7,685.35 MWD+IFR-AK-CAZ-SC (5) ~ 13,172.68 69.12 290.13 5,771.51 5,718.46 3,507.29 -10,485.50 5,977,842.00 360,807.33 0.64 7,748.87 MWD+IFR-AK-CAZ-SC (5) 13,267.98 69.20 290.27 5,805.42 5,752.37 3,538.05 -10,569.08 5,977,874.18 360,724.29 0.16 7,813.16 MWD+IFR-AK-CAZ-SC (5) 13,363.67 69.64 290.36 5,839.05 5,786.00 3,569.15 -10,653.09 5,977,906.71 360,640.83 0.47 7,877.94 MWD+IFR-AK-CAZ-SC (5) 13,458.49 69.47 290.57 5,872.17 5,819.12 3,600.21 -10,736.33 5,977,939.20 360,558.14 0.27 7,942.35 MWD+IFR-AK-CAZ-SC (5) ~ 13,554.29 68.81 290.01 5,906.29 5,853.24 3,631.26 -10,820.30 5,977,971.68 360,474.73 0.88 8,007.06 MWD+IFR-AK-CAZ-SC (5) 13,647.49 68.99 288.92 5,939.84 5,886.79 3,660.23 -10,902.28 5,978,002.05 360,393.26 1.11 8,069.04 MWD+IFR-AK-CAZ-SC (5) 13,742.18 69.06 288.09 5,973.73 5,920.68 3,688.29 -10,986.12 5,978,031.55 360,309.92 0.82 8,131.01 MWD+IFR-AK-CAZ-SC (5) 73,835.08 69.00 287.09 6,006.98 5,953.93 3,714.51 -17,068.87 5,978,059.18 360,227.70 1.01 8,190.82 MWD+IFR-AK-CAZ-SC (5) 13,926.05 68.64 286.36 6,039.85 5,986.80 3,738.92 -11,150.05 5,978,084.98 360,146.90 0.85 8,248.38 MWD+IFR-AK-CAZ-SC (5) 14,018.80 68.55 286.70 6,073.70 6,020.65 3,763.49 -11,232.83 5,978,110.96 360,064.56 0.35 8,306.75 MWD+IFR-AK-CAZ-SC (5) 14,109.39 68.85 286.23 6,106.61 6,053.56 3,787.41 -11,313.77 5,978,136.27 359,984.05 0.59 8,363.73 MWD+IFR-AK-CAZ-SC (5) ~ 14,202.93 69.06 286.47 6,140.20 6,087.15 3,811.98 -17,397.54 5,978,162.28 359,900.72 0.33 8,422.54 MWD+IFR-AK-CAZ-SC (5) 14,294.52 69.01 287.52 6,172.97 6,119.92 3,836.98 -11,479.33 5,978,788.67 359,819.38 1.07 8,480.86 MWD+IFR-AK-CAZ-SC (5) 14,387.49 69.21 289.61 6,206.12 6,153.07 3,864.64 -11,561.66 5,978,217.73 359,737.54 2.11 8,541.81 MWD+IFR-AK-CAZ-SC (5) 14,480.90 69.13 290.78 6,239.34 6,186.29 3,894.77 -11,643.60 5,978,249.27 359,656.14 1.17 8,604.82 MWD+IFR-AK-CAZ-SC (5) 14 571.37 , 68.74 290.53 6,271.86 6,218.81 3,924.55 -11,722.60 5,978,280.40 359,577.67 0.50 8,666.21 MWD+IFR-AK-CAZ-SC (5) 14,664.13 68.15 290.30 6,305.94 6,252.89 3,954.65 -11,803.45 5,978,311.88 359,497.35 0.68 8,728.70 MWD+IFR-AK-CAZ-SC (5) 14,755.92 69.20 290.67 6,339.32 6,286.27 3,984.57 -11,883.55 5,978,343.17 359,477.79 1.20 8,790.71 MWD+IFR-AK-CAZ-SC (5) I i 14,849.37 70.39 290.90 6,371.59 6,318.54 4,015.69 -77,965.54 5,978,375.69 359,336.35 1.29 t 8,854.63 MWD+IFR-AK-CAZ-SC (5) 8/17/2009 10:33:14AM Page 6 COMPASS 2003.16 Build 69 • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-o rdinate Reference: -Well CD2-73 Project: Western North Slope ` TVD Referenc®: CD2-73 (15.6 + 37.45) @ 53.05ft(Doyon 19) Site: CD2 Alpine Pa d ML) Reference: CD2-73 (15.6 + 37.45) @ 53.05ft (Doyon 19) Well: CD2-73 North Reference: True Wellbore: CD2-73 SurveylCal culation Meth od: Minimum Curvature Design: CD2-73 Database: __ CPA I EDM Production _ - - - - - i Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +FJ-W Northing ' t3asting DLS Section (ft) (°) (~) lft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 14,942.96 69.55 285.95 6,403.62 6,350.5; 4,046.38 -12,047.95 5,978,407.79 359,254.46 1.28 8,918.34 MWD+IFR-AK-CAZ-SC (5) 15,035.50 69.37 288.87 6,436.06 6,383.01 4,075.18 -12,129.69 5,978,437.99 359,173.26 1.12 8,980.06 MWD+IFR-AK-CAZ-SC (5) 15,128.47 69.26 288.25 6,468.90 6,415.85 4,102.87 -12,212.14 5,978,467.08 359,091.30 0.64 9,041.08 MWD+IFR-AK-CAZ-SC (5) 15,219.39 68.86 287.13 6,501.39 6,448.34 4,128.67 -12,293.04 5,978,494.27 359,010.87 1.23 9,099.74 MWD+IFR-AK-CAZ-SC (5) 15,310.46 68.94 286.69 6,534.18 6,481.13 4,153.39 -12,374.33 5,978,520.37 358,930.02 0.46 9,157.59 MWD+IFR-AK-CAZ-SC (5) 15,403.96 68.91 285.66 6,567.80 6,514.75 4,177.69 -12,458.12 5,978,546.11 358,846.67 1.03 9,216.16 MWD+IFR-AK-CAZ-SC (5) ~ 15,497.73 68.87 286.31 6,601.57 6,548.52 4,201.78 -12,542.21 5,978,571.64 358,763.00 0.65 9,274.68 MWD+IFR-AK-CAZ-SC (5) 15,590.87 69.54 286.61 6,634.64 6,581.59 4,226.45 -12,625.72 5,978,597.74 358,679.94 0.78 9,333.46 MWD+IFR-AK-CAZ-SC (5) 15,684.91 68.92 285.99 6,667.99 6,614.94 4,251.13 -12,710.11 5,978,623.86 358,595.99 0.90 9,392.64 MWD+IFR-AK-CAZ-SC (5) 15,778.46 68.21 285.70 6,702.17 6,649.12 4,274.91 -12,793.88 5,978,649.07 358,512.65 0.81 9,450.73 MWD+IFR-AK-CAZ-SC (5) 15,870.23 68.81 285.35 6,735.79 6,682.74 4,297.76 -12,876.15 5,978,673.33 358,430.79 0.74 9,507.34 MWD+IFR-AK-CAZ-SC (5) 15,963.51 69.11 285.22 6,769.28 6,716.23 4,320.71 -12,960.13 5,978,697.72 358,347.22 0.35 9,564.78 MWD+IFR-AK-CAZ-SC (5) 16,056.64 69.52 285.80 6,802.18 6,749.13 4,344.01 -13,044.09 5,978,722.46 358,263.69 0.73 9,622.52 MWD+IFR-AK-CAZ-SC (5) 16,149.29 69.13 285.51 6,834.89 6,781.84 4,367.40 -13,127.55 5,978,747.27 358,180.64 0.51 9,680.14 MWD+IFR-AK-CAZ-SC (5) 16,242.78 68.92 285.56 6,868.36 6,815.31 4,390.78 -13,211.66 5,978,772.09 358,096.95 0.23 9,738.02 MWD+IFR-AK-CAZ-SC (5) 16,335.43 69.28 285.77 6,901.41 6,848.36 4,414.15 -13,295.00 5,978,796.89 358,014.04 0.44 9,795.56 MWD+IFR-AK-CAZ-SC (5) i 16,428.97 69.19 285.57 6,934.57 6,881.52 4,437.78 -13,379.21 5,978,821.95 357,930.25 0.22 9,853.71 MWD+IFR-AK-CAZ-SC (5) 16,522.59 68.66 285.32 6,968.24 6,915.19 4,461.04 -13,463.41 5,978,846.66 357,846.46 0.62 9,911.53 MWD+IFR-AK-CAZ-SC (5) 16,616.70 68.28 286.40 7,002.77 6,949.72 4,484.96 -13,547.62 5,978,872.02 357,762.68 1.14 9,969.95 MWD+IFR-AK-CAZ-SC (5) 16,707.67 68.61 286.97 7,036.20 6,983.15 4,509.26 -13,628.67 5,978,897.70 357,682.07 0.69 10,027.31 MWD+IFR-AK-CAZ-SC (5) 16,801.17 69.10 287.84 7,069.92 7,016.87 4,535.34 -13,771.88 5,978,925.21 357,599.33 1.01 10,087.23 MWD+IFR-AK-CAZ-SC (5) 16,894.20 69.39 288.89 7,102.89 7,049.84 4,562.75 -13,794.44 5,978,954.03 357,517.26 1.10 10,148.06 MWD+IFR-AK-CAZ-SC (5) 16,986.13 70.38 291.48 7,134.51 7,081.46 4,592.54 -13,875.45 5,978,985.20 357,436.78 2.86 10,210.34 MWD+IFR-AK-CAZ-SC (5) 17,078.78 70.89 293.91 7,165.24 7,112.19 4,626.26 -13,956.08 5,979,020.30 357,356.75 2.53 10,276.00 MWD+IFR-AK-CAZ-SC (5) 17,170.55 71.62 296.70 7,194.73 7,141.68 4,663.41 -14,034.63 5,979,058.79 357,278.85 2.99 10,343.82 MWD+IFR-AK-CAZ-SC (5) 17,264.58 74.26 298.41 7,222.32 7,169.27 4,705.00 -14,114.31 5,979,101.73 357,199.90 3.30 10,416.13 MWD+IFR-AK-CAZ-SC (5) ~ 17,358.82 76.15 297.82 7,246.38 7,193.33 4,747.93 -14,194.67 5,979,146.04 357,120.30 2.09 10,489.95 MWD+IFR-AK-CAZ-SC (5) 17,452.60 77.88 297.39 7,267.45 7,214.40 4,790.27 -14,275.65 5,979,189.76 357,040.07 1.90 10,563.50 MWD+IFR-AK-CAZ-SC (5) 17,546.56 81.01 297.33 7,284.66 7,231.61 4,832.72 -14,357.68 5,979,233.60 356,958.79 3.33 10,637.61 MWD+IFR-AK-CAZ-SC (5) 17,639.87 84.06 297.29 7,296.79 7,243.74 4,875.16 -14,439.88 5,979,277.45 356,877.34 3.27 10,711.79 MWD+IFR-AK-CAZ-SC (5) ~ 17,689.49 84.06 297.66 7,301.92 7,248.87 4,897.93 -14,483.66 5,979,300.97 356,833.95 0.74 10,751.45 MWD+IFR-AK-CAZ-SC (5) 17,750.54 83.92 300.73 7,308.31 7,255.26 4,927.54 -14,536.66 5,979,331.48 356,781.48 5.01 10,801.30 MWD+IFR-AK-CAZ-SC (5) 17,798.13 84.86 302.93 7,312.97 7,259.92 4,952.52 -14,576.89 5,979,357.14 356,741.68 5.01 10,841.38 MWD+IFR-AK-CAZ-SC (5) 17,893.66 85.59 306.75 7,320.92 7,267.87 5,006.89 -14,655.01 5,979,412.85 356,664.51 4.06 10,924.50 MWD+IFR-AK-CAZ-SC (5) 17,987.09 86.15 309.83 7,327.65 7,274.60 5,064.63 -14,728.14 5,979,471.83 356,592.39 3.34 11,008.45 MWD+IFR-AK-CAZ-SC (5) 18,082.41 88.38 312.04 7,332.20 7,279.15 5,127.01 -14,800.06 5,979,535.42 356,521.56 3.29 11,096.04 MWD+IFR-AK-CAZ-SC (5) 18,179.22 89.86 310.76 7,333.69 7,280.64 5,191.02 -14,872.67 5,979,600.67 356,450.07 2.02 11,185.40 MWD+IFR-AK-CAZ-SC (5) 18,274.86 88.50 311.63 7,335.06 7,282.01 5,254.00 -14,944.62 5,979,664.87 356,379.21 1.69 11,273.56 MWD+IFR-AK-CAZ-SC (5) 18,370.31 88.07 315.23 7,337.91 7,284.86 5,319.58 -15,013.90 5,979,731.62 356,311.08 3.80 11,362.87 MWD+IFR-AK-CAZ-SC (5) 18,466.46 88.01 318.98 7,341.20 7,288.15 5,389.96 -15,079.29 5,979,803.12 356,246.90 3.90 11,454.80 MWD+IFR-AK-CAZ-SC (5) 8/17/2009 10:33:14AM Page 7 COMPASS 2003.16 Build 69 ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well CD2-73 Project:.. Western North Slope TVD Reference: CD2-73 (15.6 + 37.45) @ 53.05ft(Doyon 19) Site: CD2 Alpine Pad Md Reference: CD2-73 (15.6 + 37.45) @ 53.05ft (Doyon 19) Weld: CD2-73 North Refe rence: True Wellbore: CD2-73 Survey,Cal culatlon Meth od: Minimum Curvature Design: CD2-73 .Database: CPAI EDM Production -i survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +EI-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 18,562.28 89.98 322.26 7,:2.88 7,289.83 5,464.00 -15,140.07 5,979,878.18 356,187.42 3.99 11,547.98 MWD+IFR-AK-CAZ-SC (5) 18,658.15 93.25 325.97 7,340.18 7,287.13 5,541.62 -15,196.22 5,979,956.75 356,132.60 5.16 11,642.36 MWD+IFR-AK-CAZ-SC (5) 18,754.03 92.39 329.58 7,335.46 7,282.41 5,622.62 -15,247.28 5,980,038.60 356,082.95 3.87 11,737.54 MWD+IFR-AK-CAZ-SC (5) 18,849.15 91.03 331.67 7,332.62 7,279.57 5,705.47 -15,293.91 5,980,122.23 356,037.75 2.62 11,832.45 MWD+IFR-AK-CAZ-SC (5) 18,945.21 89.55 332.32 7,332.14 7,279.09 5,790.27 -15,339.02 5,980,207.79 355,994.11 1.68 11,928.45 MWD+IFR-AK-CAZ-SC (5) 19,040.71 89.86 334.80 7,332.63 7,279.58 5,875.78 -15,381.54 5,980,294.01 355,953.07 2.62 12,023.94 MWD+IFR-AK-CAZ-SC (5) 19,134.99 89.55 337.17 7,333.12 7,280.07 5,961.89 -15,419.90 5,980,380.76 355,916.20 2.54 12,118.15 MWD+IFR-AK-CAZ-SC (5) 19,229.73 91.65 338.81 7,332.12 7,279.07 6,049.71 -15,455.40 5,980,469.17 355,882.21 2.81 12,212.65 MWD+IFR-AK-CAZ-SC (5) 19,325.72 91.16 337.51 7,329.77 7,276.72 6,138.78 -15,491.10 5,980,558.83 355,848.05 1.45 12,308.35 MWD+IFR-AK-CAZ-SC (5) 19,421.11 91.34 336.19 7,327.69 7,274.64 6,226.47 -15,528.59 5,980,647.14 355,812.07 1.40 12,403.60 MWD+IFR-AK-CAZ-SC (5) 19,516.56 90.97 334.92 7,325.76 7,272.71 6,313.34 -15,568.08 5,980,734.68 355,774.08 1.39 12,498.99 MWD+IFR-AK-CAZ-SC (5) 19,612.29 90.35 334.82 7,324.66 7,271.61 6,400.01 -15,608.73 5,980,822.02 355,734.93 0.66 12,594.71 MWD+IFR-AK-CAZ-SC (5) 19,708.01 89.92 334.59 7,324.44 7,271.39 6,486.55 -15,649.63 5,980,909.24 355,695.53 0.51 12,690.42 MWD+IFR-AK-CAZ-SC (5) 19,803.53 90.11 333.94 7,324.41 7,271.36 6,572.59 -15,691.11 5,980,995.98 355,655.54 0.71 12,785.94 MWD+IFR-AK-CAZ-SC (5) 19,898.92 90.29 333.94 7,324.08 7,271.03 6,658.28 -15,733.01 5,981,082.37 355,615.11 0.19 12,881.33 MWD+IFR-AK-CAZ-SC (5) 19,993.74 89.86 333.97 7,323.95 7,270.90 6,743.48 -15,774.65 5,981,168.26 355,574.95 0.45 12,976.15 MWD+IFR-AK-CAZ-SC (5) 20,089.23 89.61 333.95 7,324.40 7,271.35 6,829.27 -15,816.57 5,981,254.75 355,534.52 0.26 13,071.63 MWD+IFR-AK-CAZ-SC (5) 20,184.99 89.43 335.03 7,325.20 7,272.15 6,915.69 -15,857.81 5,981,341.86 355,494.77 1.14 13,167.39 MWD+IFR-AK-CAZ-SC (5) 20,281.00 90.54 336.11 7,325.22 7,272.17 7,003.10 -15,897.51 5,981,429.94 355,456.57 1.61 13,263.36 MWD+IFR-AK-CAZ-SC (5) 20,376.24 89.92 335.74 7,324.84 7,271.79 7,090.06 -15,936.36 5,981,517.54 355,419.22 0.76 13,358.54 MWD+IFR-AK-CAZ-SC (5) 20,471.93 90.17 333.03 7,324.77 7,271.72 7,176.33 -15,977.73 5,981,604.50 355,379.35 2.84 13,454.22 MWD+IFR-AK-CAZ-SC (5) 20,567.61 89.61 329.73 7,324.95 7,271.90 7,260.31 -16,023.55 5,981,689.25 355,334.98 3.50 13,549.79 MWD+IFR-AK-CAZ-SC (5) 20,663.56 90.35 330.63 7,324.98 7,271.93 7,343.56 -16,071.26 5,981,773.29 355,288.71 1.21 13,645.52 MWD+IFR-AK-CAZ-SC (5) 20,756.86 90.23 332.51 7,324.51 7,271.46 7,425.60 -16,115.68 5,981,856.08 355,245.71 2.02 13,738.73 MWD+IFR-AK-CAZ-SC (5) 20,854.78 91.40 335.17 7,323.12 7,270.07 7,513.47 -16,158.84 5,981,944.67 355,204.07 2.97 13,836.63 MWD+IFR-AK-CAZ-SC (5) 20,949.09 90.85 336.21 7,321.27 7,268.22 7,599.40 -16,197.66 5,982,031.25 355,166.73 1.25 13,930.88 MWD+IFR-AK-CAZ-SC (5) 21,045.10 90.85 336.06 7,319.84 7,266.79 7,687.19 -16,236.50 5,982,119.69 355,129.41 0.16 14,026.81 MWD+IFR-AK-CAZ-SC (5) 21,140.22 89.36 334.96 7,319.67 7,266.62 7,773.75 -16,275.93 5,982,206.90 355,091.48 1.95 14,121.90 MWD+IFR-AK-CAZ-SC (5) 21,235.93 89.30 333.32 7,320.79 7,267.74 7,859.87 -16,317.67 5,982,293.72 355,051.22 1.71 14,217.60 MWD+IFR-AK-CAZ-SC (5) 21,331.34 90.54 333.64 7,320.92 7,267.87 7,945.24 -16,360.27 5,982,379.80 355,010.10 1.34 14,313.00 MWD+IFR-AK-CAZ-SC (5) 21,427.17 89.98 332.47 7,320.49 7,267.44 8,030.66 -16,403.69 5,982,465.95 354,968.15 1.35 14,408.81 MWD+IFR-AK-CAZ-SC (5) 21,522.24 89.36 330.99 7,321.03 7,267.98 8,114.39 -16,448.72 5,982,550.43 354,924.57 1.69 14,503.81 MWD+IFR-AK-CAZ-SC (5) 21,617.77 89.49 330.55 7,321.99 7,268.94 8,197.75 -16,495.36 5,982,634.57 354,879.37 0.48 14,599.18 MWD+IFR-AK-CAZ-SC (5) 21,712.90 88.44 330.08 7,323.71 7,270.66 8,280.38 -16,542.47 5,982,717.99 354,833.70 1.21 14,694.09 MWD+IFR-AK-CAZ-SC (5) 21,743.07 87.14 330.61 7,324.87 7,271.82 8,306.58 -16,557.38 5,982,744.44 354,819.23 4.65 14,724.18 MWD+IFR-AK-CAZ-SC (5) 21,810.00 87.14 330.61 7,328.21 7,275.16 8,364.82 -16,590.19 5,982,803.23 354,787.44 0.00 14,790.91 PROJECTED to TD 8/17/2009 10:33:14AM Page 8 COMPASS 2003.16 Build 69 ConocoPhillips(Alaska) Inc. Western North Slope CD2 Alpine Pad CD2-73PB1 501032059070 ., ~..; ; Definitive Survey Report 17 August, 2009 mix= ~~» Sperry Drilling Service • • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well CD2-73 Project: Westem North Slope TVD Reference: CD2-73 (15.6 + 37.45) @ 53.05ft(Doyon 19) Site: CD2 Alpine Pad MQ1ReferenCe: CD2-73 (15.6 + 37.45) @ 53.05ft(Doyon 19) Well: CD2-73 North Reference: True Wellbore: CD2-73PB1 Survey Calculation Method: Minimum Curvature Design: CD2-73P61 Database: CPAI EDM Production Project Westem North Slope Map System: US State Plane 1927 (F~cact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD2-73 Well Position +N/-S 0.00 ft Northing: 5,974,155.46ft Latitude: 70° 20' 15.365 N +E/-W 0.00 ft Easting: 371,230.20 ft Longitude: 151° 2' 41.450 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 15.60ft Wellbore CD2-73P61 Magnetics Model Name Sample Date Declination Dip Angle Fleld Strength BGGM2007 1 /5/009 21.73 . 80.69 5Z598~ Design CD2-73PB1 Audit Notes: Pennit to Drill: 20&196 Version: 1.0 Phase: ACTUAL Tie On Depth: 37.45 Vertical Section: Depth From (TVD) +Nl-S +E/-W Direction ~ (ft) (ft) (ft) (°) ~ 37.45 0.00 0.00 334.00 Survey Program Date From To (ft) (ft) Survey (Wellbore) 84.00 820.00 CD2-73PB1 Gyro (CD2-73P61) 902.46 1,137.95 CD2-73PB1 MWD (CD2-73PB1) 1,200.00 1,295.00 CD2-73P61 Gyro (CD2-73PB1) 1,326.78 3,609.53 CD2-73PB1 MWD (CD2-73PB1) 3,755.10 17,803.70 CD2-73P61 MWD (CD2-73PB1) ~u rvey MD Inc Azi TVD TVDSS +N/-S Ift) 1°1 (°) (ftl (ftl (ft) ~ 37..5 0. 0 37.45 -15.60 0. 0 0.00 84.00 0.18 359.87 84.00 30.95 0.07 176.00 0.40 0.00 176.00 122.95 0.54 268.00 0.58 0.81 268.00 214.95 1.33 360.00 0.78 3.48 359.99 306.94 2.42 452.00 1.06 334.39 451.98 398.93 3.81 543.00 2.89 308.36 542.92 489.87 5.99 636.00 4.97 309.83 635.70 582.65 10.03 728.00 7.38 310.24 727.16 674.11 16.40 820.00 9.94 313.29 818.10 765.05 25.66 Tool Name Description Survey Date GYD-GC-SS Gyrodata gyro single shots 1/5/2009 12: MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/5/2009 12: GYD-GC-SS Gyrodata gyro single shots 1/5/2009 12: MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/5/2009 12: MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/30/2009 1: Map Map Vert ical +E/-W Northing Easting DLS 'Sec tion (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 0.00 5,974,155.46 371,230.20 0.00 0.00 UNDEFINED 0.00 5,974,155.53 371,230.20 0.39 0.07 GYD-GC-SS (1) 0.00 5,974,156.00 371,230.21 0.24 0.48 GYD-GC-SS (1) 0.01 5,974,156.78 371,230.23 0.20 1.19 GYD-GC-SS (1) 0.05 5,974,157.87 371,230.29 0.22 2.15 GYD-GC-SS (1) -0.28 5,974,159.27 371,229.99 0.58 3.55 GYD-GC-SS (1) -2.44 5,974,161.49 371,227.86 2.19 6.46 GYD-GC-SS (1) -7.37 5,974,165.61 371,223.00 2.24 12.25 GYD-GC-SS (1) -14.95 5,974,172.11 371,215.54 2.62 21.29 GYD-GC-SS (1) -25.24 5,974,181.55 371,205.41 2.83 34.13 GYD-GC-SS (1) 8/17/2009 10:09:58AM Page 2 COMPASS 2003.16 Build 69 • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Ina Local Co-ordinat>~ Reference: Well CD2-73 Project: Western North Slope ND Reference: CD2-73 (15.6 + 37.45) @ 53.05ft(Doyon 19) Site: CD2 Alpine Pad MO' Refere nce; CD2-73 (15.6 + 37.45) @ 53.05ft(Doyon 19) Well: CD2-73 North Reference: True Wellbore: CD2-73P61 Survey Ca lculation Meth od: Minimum Cu rvature Design: CD2-73P61 - -- Database: CPA I EDM Production Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-5 +E/-W Northing EasUng DLS Section lftl (°) (°) ln) (ft) (ft) Ift) (ftl (~) (°I100') (ft) Survey Tool Name 502.46 12.07 315.36 859.04 845.59 36.73 -36.42 5,914,192.80 371,194.41 2.65 48.98 MWD+IFR-AK-GAZ-SG~21 947.40 13.98 313.72 942.82 889.77 43.85 -43.62 5,974,200.05 371,187.34 4.38 58.54 MWD+IFR-AK-CAZ-SC (2) 1,042.91 17.48 313.18 1,034.74 981.69 61.65 -62.42 5,974,218.16 371,168.85 3.67 82.77 MWD+IFR-AK-CAZ-SC (2) 1,137.95 20.70 314.36 1,124.54 1,071.49 83.17 -84.85 5,974,240.06 371,146.80 3.41 111.94 MWD+IFR-AK-CAZ-SC (2) 1,200.00 23.25 310.65 7,182.08 1,129.03 98.81 -101.98 5,974,256.00 371,129.94 4.68 133.52 GYD-GC-SS (3) 1,295.00 27.24 306.11 1,268.00 1,214.95 123.85 -133.79 5,974,281.58 371,098.57 4.67 169.97 GYD-GC-SS (3) 1,326.78 28.29 305.59 1,296.12 1,243.07 132.52 -145.79 5,974,290.45 371,086.72 3.39 183.02 MWD+IFR-AK-CAZ-SC (4) 1,372.72 30.04 304.01 1,336.24 1,283.19 145.29 -164.18 5,974,303.54 371,068.56 4.16 202.56 MWD+IFR-AK-CAZ-SC (4) I 1,422.51 32.71 301.61 1,378.74 1,325.69 159.32 -185.97 5,974,317.93 371,047.01 5.92 224.72 MWD+IFR-AK-CAZ-SC (4) 1,470.81 36.03 298.37 1,418.61 1,365.56 172.91 -209.59 5,974,331.93 371,023.63 7.85 247.29 MWD+IFR-AK-CAZ-SC (4) 1,516.95 38.25 297.62 1,455.39 1,402.34 185.98 -234.19 5,974,345.42 370,999.26 4.91 269.82 MWD+IFR-AK-CAZ-SC (4) 1,563.78 40.34 297.13 1,491.63 1,438.58 199.62 -260.53 5,974,359.50 370,973.16 4.51 293.62 MWD+IFR-AK-CAZ-SC (4) 1,612.89 42.43 297.00 1,528.47 1,475.42 214.39 -289.44 5,974,374.77 370,944.51 4.26 319.57 MWD+IFR-AK-CAZ-SC (4) 1,660.61 44.85 296.66 1,563.00 1,509.95 229.25 -318.82 5,974,390.13 370,915.39 5.10 345.81 MWD+IFR-AK-CAZ-SC (4) 1,707.95 46.62 295.97 1,596.04 1,542.99 244.27 -349.21 5,974,405.67 370,885.26 3.88 372.64 MWD+IFR-AK-CAZ-SC (4) 1,757.29 48.34 293.26 1,629.39 1,576.34 259.41 -382.27 5,974,421.37 370,852.47 5.34 400.73 MWD+IFR-AK-CAZ-SC (4) 1,803.36 50.27 292.28 1,659.43 1,606.38 272.92 -414.48 5,974,435.43 370,820.50 4.49 427.00 MWD+IFR-AK-CAZ-SC (4) 1,852.02 53.02 291.51 1,689.62 1,636.57 287.15 -449.88 5,974,450.26 370,785.35 5.79 455.30 MWD+IFR-AK-CAZ-SC (4) 1,898.72 55.19 292.06 1,717.00 1,663.95 301.19 -485.01 5,974,464.90 370,750.48 4.74 483.32 MWD+IFR-AK-CAZ-SC (4) 1,944.50 57.38 291.19 1,742.41 1,689.36 315.22 -520.41 5,974,479.54 370,715.33 5.04 511.44 MWD+IFR-AK-CAZ-SC (4) 1,993.83 59.32 290.65 1,768.30 1,715.25 330.21 -559.63 5,974,495.20 370,676.37 4.04 542.11 MWD+IFR-AK-CAZ-SC (4) 2,041.49 61.43 289.45 1,791.85 1,738.80 344.41 -598.55 5,974,510.06 370,637.70 4.94 571.94 MWD+IFR-AK-CAZ-SC (4) 2,088.45 62.93 288.76 1,813.77 1,760.72 358.00 -637.79 5,974,524.32 370,598.70 3.45 601.35 MWD+IFR-AK-CAZ-SC (4) 2,134.07 64.50 287.53 1,833.97 1,780.92 370.73 -676.66 5,974,537.72 370,560.06 4.21 629.84 MWD+IFR-AK-CAZ-SC (4) 2,183.71 65.82 287.72 1,854.82 1,801.77 384.37 -719.59 5,974,552.10 370,517.38 2.68 660.92 MWD+IFR-AK-CAZ-SC (4) i 2,231.30 67.19 287.22 1,873.80 1,820.75 397.47 -761.22 5,974,565.91 370,475.98 3.04 690.94 MWD+IFR-AK-CAZ-SC (4) 2,278.62 67.18 286.72 1,892.15 1,839.10 410.20 -802.94 5,974,579.35 370,434.49 0.97 720.67 MWD+IFR-AK-CAZ-SC (4) 2,373.77 68.68 286.59 1,927.90 1,874.85 435.47 -887.41 5,974,606.07 370,350.47 1.58 780.42 MWD+IFR-AK-CAZ-SC (4) 2,468.04 68.75 285.88 1,962.12 1,909.07 460.03 -971.75 5,974,632.07 370,266.57 0.71 839.46 MWD+IFR-AK-CAZ-SC (4) 2,563.23 69.47 287.26 1,996.06 1,943.01 485.40 -1,056.99 5,974,658.89 370,181.79 1.55 899.62 MWD+IFR-AK-CAZ-SC (4) 2,657.28 69.28 286.68 2,029.19 1,976.14 511.09 -1,141.18 5,974,686.02 370,098.06 0.61 959.62 MWD+IFR-AK-CAZ-SC (4) 2,752.77 68.81 286.31 2,063.34 2,010.29 536.41 -1,226.68 5,974,712.81 370,013.01 0.61 1,019.86 MWD+IFR-AK-CAZ-SC (4) 2,847.79 69.55 287.19 2,097.11 2,044.06 562.00 -1,311.72 5,974,739.86 369,928.43 1.16 1,080.15 MWD+IFR-AK-CAZ-SC (4) 2,942.96 70.25 287.81 2,129.82 2,076.77 588.88 -1,396.96 5,974,768.19 369,843.67 0.96 1,141.67 MWD+IFR-AK-CAZ-SC (4) 3,037.69 67.44 288.14 2,164.00 2,110.95 616.14 -1,480.99 5,974,796.89 369,760.13 2.98 1,203.00 MWD+IFR-AK-CAZ-SC (4) 3,133.32 68.23 287.98 2,200.08 2,147.03 643.59 -1,565.19 5,974,825.78 369,676.42 0.84 1,264.59 MWD+IFR-AK-CAZ-SC (4) 3,228.85 69.57 287.11 2,234.47 2,181.42 670.46 -1,650.16 5,974,854.10 369,591.93 1.64 1,325.99 MWD+IFR-AK-CAZ-SC (4) ~ 3,323.77 69.75 287.48 2,267.47 2,214.42 696.92 -1,735.14 5,974,882.01 369,507.42 0.41 1,387.02 MWD+IFR-AK-CAZ-SC (4) 3,419.04 68.89 287.65 2,301.11 2,248.06 723.81 -1,820.11 5,974,910.36 369,422.93 0.92 1,448.45 MWD+IFR-AK-CAZ-SC (4) 3,514.42 69.52 286.57 2,334.97 2,281.92 750.05 -1,905.33 5,974,938.05 369,338.18 1.25 1,509.38 MWD+IFR-AK-CAZ-SC (4) 8/17/2009 10:09:58AM Page 3 COMPASS 2003.16 Build 69 • • ConocoP hillips Definitive Surrey Report '~-Company: ConocoPhillips(Alaska) Inc. local Go-ord+nate Reference: Well CD2-73 Project: Western North Slope TVD Reference: CD2-73 (15.6 + 37.45) @ 53.05ft(Doyon 19) Site: CD2 Alpine Pad MD Refere nce: CD2-73 (15.6 + 37.45) @ 53.05ft(Doyon 19) Well: CD2-73 North Reference: True Wellbore: CD2-73P61 Survey Ca lculation Method: Minimum Curvature Design: CD2-73PB1 Database: CPAI EDM Production Survey Map Map Vertical MD (ftl Inc (°) Azi (°) ND (ft) TVDSS lft) +NI-S (ft) +E!-W Ift) Northing (ft) Easting DLS (ft) (°1100') Section '' (ft) Surrey Tool Name 3,609.53 69.98 227.05 2,367.89 2,314.84 775.85 -1,590.75 5,974,965.32 369,253.23 0.68 1,570.02 MWD+IFR-AK-CAZ-SC (4) 3,755.10 70.09 288.81 2,417.60 2,364.55 817.97 -2,720.92 5,975,009.66 369,123.81 1.14 1,664.94 MWD+IFR-AK-CAZ-SC (5) 3,850.29 69.70 288.80 2,450.32 2,397.27 846.79 -2,205.54 5,975,039.92 369,039.71 0.41 1,727.93 MWD+IFR-AK-CAZ-SC (5) 3,945.70 69.33 288.55 2,483.71 2,430.66 875.40 -2,290.21 5,975,069.99 368,955.55 0.46 1,790.77 MWD+IFR-AK-CAZ-SC (5) 4,040.52 68.90 288.61 2,517.51 2,464.46 903.63 -2,374.18 5,975,099.65 368,872.08 0.46 1,852.95 MWD+IFR-AK-CAZ-SC (5) 4,134.99 68.84 287.18 2,551.57 2,498.52 930.71 -2,458.03 5,975,128.16 368,788.71 1.41 1,914.05 MWD+IFR-AK-CAZ-SC (5) 4,230.54 69.21 286.09 2,585.77 2,532.72 956.25 -2,543.52 5,975,155.16 368,703.68 1.13 1,974.47 MWD+IFR-AK-CAZ-SC (5) 4,326.18 68.89 286.02 2,619.97 2,566.92 980.95 -2,629.35 5,975,181.33 368,618.29 0.34 2,034.30 MWD+IFR-AK-CAZ-SC (5) 4,420.85 68.85 285.14 2,654.10 2,601.05 1,004.67 -2,714.41 5,975,206.50 368,533.66 0.87 2,092.91 MWD+IFR-AK-CAZ-SC (5) 4,516.51 69.00 284.43 2,688.50 2,635.45 1,027.44 -2,800.72 5,975,230.76 368,447.77 0.77 2,151.21 MWD+IFR-AK-CAZ-SC (5) ~ 4,609.78 68.53 284.22 2,722.28 2,669.23 1,048.95 -2,884.95 5,975,253.71 368,363.92 0.55 2,207.47 MWD+IFR-AK-CAZ-SC (5) 4,705.66 68.81 284.81 2,757.15 2,704.10 1,071.34 -2,977.41 5,975,277.57 368,277.87 0.64 2,265.49 MWD+IFR-AK-CAZ-SC (5) 4,800.54 69.09 285.56 2,791.23 2,738.18 1,094.53 -3,056.87 5,975,302.23 368,192.83 0.79 2,323.80 MWD+IFR-AK-CAZ-SC (5) 4,896.61 68.61 286.83 2,825.90 2,772.85 1,119.52 -3,142.97 5,975,328.69 368,107.23 1.33 2,383.98 MWD+IFR-AK-CAZ-SC (5) 4,991.34 68.37 287.74 2,860.63 2,807.58 1,145.71 -3,227.06 5,975,356.31 368,023.55 0.93 2,444.40 MWD+IFR-AK-CAZ-SC (5) 5,086.89 69.04 288.44 2,895.33 2,842.28 1,173.35 -3,317.68 5,975,385.41 367,939.42 0.98 2,506.35 MWD+IFR-AK-CAZ-SC (5) 5,181.64 69.29 289.10 2,929.04 2,875.99 1,201.85 -3,395.53 5,975,475.33 367,856.09 0.70 2,568.71 MWD+IFR-AK-CAZ-SC (5) 5,276.92 69.17 288.73 2,962.82 2,909.77 1,230.72 -3,479.80 5,975,445.65 367,772.33 0.38 2,637.61 MWD+IFR-AK-CAZ-SC (5) 5,371.23 68.99 288.66 2,996.50 2,943.45 1,258.96 -3,563.25 5,975,475.32 367,689.38 0.20 2,693.57 MWD+IFR-AK-CAZ-SC (5) 5,466.57 69.37 288.24 3,030.38 2,977.33 1,287.16 -3,647.78 5,975,504.96 367,605.35 0.57 2,755.98 MWD+IFR-AK-CAZ-SC (5) 5,561.58 69.22 288.89 3,063.98 3,010.93 1,315.46 -3,732.03 5,975,534.70 367,521.61 0.66 2,818.34 MWD+IFR-AK-CAZ-SC (5) 5,657.18 69.22 288.87 3,097.89 3,044.84 1,344.38 -3,816.60 5,975,565.07 367,437.55 0.02 2,881.41 MWD+IFR-AK-CAZ-SC (5) 5,751.24 69.29 288.54 3,131.21 3,078.16 7,372.59 -3,899.92 5,975,594.70 367,354.74 0.34 2,943.29 MWD+IFR-AK-CAZ-SC (5) 5,846.93 69.41 286.99 3,164.96 3,111.91 1,399.91 -3,985.19 5,975,623.48 367,269.96 1.52 3,005.22 MWD+IFR-AK-CAZ-SC (5) 5,941.45 69.57 285.93 3,198.08 3,145.03 7,424.99 -4,070.09 5,975,650.01 367,185.51 1.06 3,064.98 MWD+IFR-AK-CAZ-SC (5) 6,037.13 69.14 285.86 3,231.81 3,178.76 1,449.51 -4,756.20 5,975,676.01 367,099.84 0.45 3,124.77 MWD+IFR-AK-CAZ-SC (5) 6,131.96 69.04 286.11 3,265.66 3,212.61 1,473.91 -4,241.36 5,975,701.86 367,015.12 0.27 3,184.03 MWD+IFR-AK-CAZ-SC (5) ~ 6,227.24 69.23 286.61 3,299.59 3,246.54 1,498.99 -4,326.78 5,975,728.40 366,930.14 0.53 3,244.02 MWD+IFR-AK-CAZ-SC (5) 6,322.34 69.49 287.19 3,333.11 3,280.06 1,524.86 -4,411.94 5,975,755.72 366,845.46 0.63 3,304.60 MWD+IFR-AK-CAZ-SC (5) 6,417.36 69.43 287.02 3,366.45 3,313.40 7,551.03 -4,496.98 5,975,783.35 366,760.88 0.18 3,365.40 MWD+IFR-AK-CAZ-SC (5) 6,512.62 69.20 286.65 3,400.10 3,347.05 1,576.84 -4,582.28 5,975,810.62 366,676.04 0.44 3,425.99 MWD+IFR-AK-CAZ-SC (5) 6,608.18 68.99 286.73 3,434.20 3,381.15 1,602.48 -4,667.79 5,975,837.72 366,591.00 0.23 3,486.52 MWD+IFR-AK-CAZ-SC (5) 6,702.55 69.20 286.68 3,467.87 3,414.82 1,627.82 -4,752.23 5,975,864.50 366,507.01 0.23 3,546.31 MWD+IFR-AK-CAZ-SC (5) 6,797.78 69.41 286.62 3,501.53 3,448.48 1,653.34 -4,837.58 5,975,891.49 366,422.12 0.23 3,606.67 MWD+IFR-AK-CAZ-SC (5) 6,892.94 69.08 286.18 3,535.25 3,482.20 1,678.47 -4,922.94 5,975,918.07 366,337.21 0.55 3,666.67 MWD+IFR-AK-CAZ-SC (5) 6,988.53 69.17 286.35 3,569.31 3,516.26 1,703.48 -5,008.68 5,975,944.55 366,251.92 0.19 3,726.74 MWD+IFR-AK-CAZ-SC (5) 7,083.52 68.89 286.37 3,603.30 3,550.25 1,728.47 -5,093.79 5,975,970.99 366,167.26 0.30 3,786.50 MWD+IFR-AK-CAZ-SC (5) 7,178.95 68.70 286.27 3,637.82 3,584.77 1,753.47 -5,179.17 5,975,997.45 366,082.32 0.22 3,846.40 MWD+IFR-AK-CAZ-SC (5) 7,273.81 68.83 286.81 3,672.18 3,619.13 1,778.64 -5,263.93 5,976,024.08 365,998.01 0.55 3,906.79 MWD+IFR-AK-CAZ-SC (5) 7,368.51 68.88 287.77 3,706.34 3,653.29 1,804.89 -5,348.26 5,976,051.77 365,914.15 - 0.95 3,966.75 MWD+IFR-AK-CAZ-SC (5) - 8/17/2009 10:09:58AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc Project: Western North Slope Site: CD2 Alpine Pad Well: CD2-73 Wellbore: CD2-73P61 Design: CD2-73P61 Survey MD Inc fftl 1°) 7,464.11 68.44 7,559.98 69.06 7,654.62 69.56 7,749.76 69.42 7,844.77 69.41 7,940.30 69.55 8,034.88 69.39 8,129.93 69.08 8,225.43 69.09 8,320.60 68.77 8,416.13 68.98 8,511.57 69.57 8,606.27 69.57 8,700.98 69.14 8,795.84 69.26 8,890.96 69.36 8,986.15 69.23 9,081.06 69.17 9,176.24 69.44 9,271.30 69.55 9,366.34 69.48 9,460.78 69.37 9,556.46 69.04 9,651.44 69.10 9,746.39 69.04 9,841.74 68.97 9,936.48 68.95 10,032.26 68.94 10,126.06 69.07 10,221.03 68.82 10,316.00 68.97 10,411.46 69.04 10,506.84 68.95 10,602.10 69.40 10,697.17 69.03 10,792.88 68.85 10,887.82 68.84 10,983.21 68.63 11,078.13 69.26 11,172.64 69.53 +NI-S (ft) 1,832.23 1,860.26 1,888.62 1,917.58 1,946.35 1,974.24 2,001.04 2,027.10 2,052.11 2,076.38 2,100.34 2,123.80 2,146.91 2,169.97 2,193.39 2,217.73 2,242.89 2,268.87 2,295.40 2,322.01 2,348.73 2,375.09 2,401.76 2,428.75 2,456.08 2,483.46 2,511.01 2,539.32 2,566.86 2,594.30 2,621.51 2,649.15 2,676.77 2,703.33 2,728.50 2,752.61 2,776.04 2,799.69 2,823.65 2,848.38 Local Ca-ordinate Reference' ND' Reference: MD Reference: North Reference: Survey Calculation Method: Database: - Map +E/-W Northing (ft) (ft} -5,433.00 5,976,080.56 -5,517.85 5,976,110.04 -5,601.72 5,976,139.83 -5,685.99 5,976,170.23 -5,770.15 5,976,200.44 -5,855.16 5,976,229.79 -5,939.58 5,976,258.03 -6,024.55 5,976,285.54 -6,110.18 5,976,312.02 -6,195.60 5,976,337.75 -6,281.43 5,976,363.18 -6,367.56 5,976,388.10 -6,453.24 5,976,412.69 -6, 538.81 5,976,437.21 -6,624.34 5,976,462.10 -6,709.94 5,976,487.89 -6,795.35 5,976,514.52 -6,880.18 5,976,541.95 -6,965.18 5,976,569.93 -7,050.15 5,976,597.99 -7,135.07 5,976,626.17 -7,219.46 5,976,653.97 -7,304.84 5,976,682.10 -7,389.35 5,976,710.54 -7,473.72 5,976,739.31 -7,558.42 5,976,768.14 -7,642.45 5,976,797.12 -7,727.23 5,976,826.88 -7,810.36 5,976,855.85 -7,894.63 5,976,884.73 -7,978.95 5,976,913.38 -8,063.68 5,976,942.46 -8,148.33 5,976,971.53 -8, 233.31 5, 976, 999.54 -8,318.56 5,977,026.17 -8,404.55 5,977,051.76 -8,489.94 5,977,076.64 -8,575.63 5,977,101.76 -8,660.91 5,977,127.18 -8,745.85 5,977,153.36 f. J `Neil CD2-73 CD2-73 (15.6 + 37.45) @ 53.05ft(Doyon 19) CD2-73 (15.6 + 37.45) @ 53.05ft(Doyon 19) True Minimum Curvature GPAI EDM Production Map vertical Fasting DLS Section (ft) (°1100') (ft) Survey Tool Name 365,829.90 0.51 4,028.47 MWD+IFR-AI<-Gi1Z-SG (5) 365,745.56 0.85 4,090.86 MWD+IFR-AK-CAZ-SC (5) 365,662.19 0.58 4,153.11 MWD+IFR-AK-CAZ-SC (5) 365,578.44 0.36 4,216.08 MWD+IFR-AK-CAZ-SC (5) 365,494.79 0.50 4,278.84 MWD+IFR-AK-CAZ-SC (5) 365,410.28 0.90 4,341.17 MWD+IFR-AK-CAZ-SC (5) 365,326.34 0.26 4,402.26 MWD+IFR-AK-CAZ-SC (5) 365,241.83 0.96 4,462.93 MWD+IFR-AK-CAZ-SC (5) 365,156.66 0.60 4,522.95 MWD+IFR-AK-CAZ-SC (5) 365,071.67 0.41 4,582.22 MWD+IFR-AK-CAZ-SC (5) 364,986.27 0.36 4,641.37 MWD+IFR-AK-CAZ-SC (5) 364,900.56 0.75 4,700.21 MWD+IFR-AK-CAZ-SC (5) 364,815.30 0.16 4,758.55 MWD+IFR-AK-CAZ-SC (5) 364,730.14 0.50 4,816.79 MWD+IFR-AK-CAZ-SC (5) 364,645.03 0.67 4,875.33 MWD+IFR-AK-CAZ-SC (5) 364,559.88 0.45 4,934.72 MWD+IFR-AK-CAZ-SC (5) 364,474.92 0.65 4,994.78 MWD+IFR-AK-CAZ-SC (5) 364,390.55 0.57 5,055.32 MWD+IFR-AK-CAZ-SC (5) 364,306.03 0.28 5,116.42 MWD+IFR-AK-CAZ-SC (5) 364,221.54 0.15 5,177.59 MWD+IFR-AK-CAZ-SC (5) 364,137.09 0.09 5,238.84 MWD+IFR-AK-CAZ-SC (5) 364,053.17 0.33 5,299.53 MWD+IFR-AK-CAZ-SC (5) 363,968.27 0.46 5,360.92 MWD+IFR-AK-CAZ-SC (5) 363,884.24 0.43 5,422.23 MWD+IFR-AK-CAZ-SC (5) 363,800.36 0.07 5,483.77 MWD+IFR-AK-CAZ-SC (5) 363,716.15 0.11 5,545.51 MWD+IFR-AK-CAZ-SC (5) 363,632.62 0.56 5,607.11 MWD+IFR-AK-CAZ-SC (5) 363,548.34 0.05 5,669.72 MWD+IFR-AK-CAZ-SC (5) 363,465.70 0.35 5,730.92 MWD+IFR-AK-CAZ-SC (5) 363,381.92 0.37 5,792.52 MWD+IFR-AK-CAZ-SC (5) 363,298.09 0.16 5,853.94 MWD+IFR-AK-CAZ-SC (5) 363,213.85 0.39 5,915.92 MWD+IFR-AK-CAZ-SC (5) 363,129.70 0.38 5,977.86 MWD+IFR-AK-CAZ-SC (5) 363,045.19 1.13 6,038.98 MWD+IFR-AK-CAZ-SC (5) 362,960.40 0.84 6,098.97 MWD+IFR-AK-CAZ-SC (5) 362,874.83 0.81 6,158.35 MWD+IFR-AK-CAZ-SC (5) 362,789.87 0.16 6,216.83 MWD+IFR-AK-CAZ-SC (5) 362,704.60 0.22 6,275.65 MWD+IFR-AK-CAZ-SC (5) 362,619.75 0.83 6,334.57 MWD+IFR-AK-CAZ-SC (5) 362,535.26 0.62 6,394.03 MWD+IFR-AK-CAZ-SC (5) 8/17/2009 10:09:58AM Page 5 COMPASS 2003.16 Buiid 69 Azi 288.00 288.56 288.80 289.13 288.62 287.71 287.51 286.59 285.98 285.74 285.45 285.02 285.18 284.98 285.65 286.09 286.74 287.32 287.34 287.44 287.50 287.19 287.50 287.93 287.96 287.87 288.44 288.49 288.17 287.90 287.87 288.26 287.88 286.83 286.07 285.26 285.42 285.44 285.95 286.51 TVD (ft) 3, 741.13 3,775.88 3,809.32 3,842.65 3,876.06 3,909.54 3,942.71 3,976.41 4,010.50 4,044.72 4,079.15 4,112.92 4,145.98 4,179.37 4,213.06 4,246.66 4,280.32 4,314.02 4,347.66 4,380.96 4,414.22 4,447.41 4,481.37 4,515.30 4,549.22 4,583.39 4,617.40 4,651.81 4,685.42 4,719.54 4,753.73 4, 787.93 4,822.12 4,855.99 4,889.73 4,924.12 4,958.38 4,992.98 5,027.08 5,060.34 TVDSS (ft) 3,688.08 3,722.83 3,756.27 3,789.60 3,823.01 3,856.49 3,889.66 3,923.36 3,957.45 3,991.67 4,026.10 4,059.87 4,092.93 4,126.32 4,160.01 4,193.61 4,227.27 4,260.97 4,294.61 4,327.91 4,361.17 4,394.36 4,428.32 4,462.25 4,496.17 4,530.34 4,564.35 4,598.76 4,632.37 4,666.49 4,700.68 4,734.88 4,769.07 4,802.94 4,836.68 4,871.07 4,905.33 4,939.93 4,974.03 5,007.29 • i ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Ca-ordinate Reference: Well CD2-73 Project: Western North Slope TVD Reference: CD2-73 (15.6 + 37.45) @ 53.05ft(Doyon 19) 'Site: CD2 Alpine Pad Mt7 Reference: CD2-73 (15.6 + 37.45) @ 53.05ft (Doyon 19) Welt: CD2-73 North Reference- True Wellbore: CD2-73PB1 Survey CalCUlatlon Method: Minimum Curvature Design: CD2-73PB1 Database:` CPAI EDM Production Survey Map MD Inc Azi TVD TVDSS +N/-S +E1-W Northing Ift) (°) 1°) (ft) ln) fftl (ft) (it) 11,268.05 68.80 286.57 5,094.28 5,041.23 2,873.76 $,831.33 5,977,180.21 11,363.56 68.51 286.54 5,129.04 5,075.99 2,899.11 -8,916.60 5,977,207.01 11,458.60 69.10 286.57 5,163.40 5,110.35 2,924.36 -9,001.54 5,977,233.71 11,553.75 69.09 287.08 5,197.35 5,144.30 2,950.09 -9,086.62 5,977,260.90 11,649.00 69.14 288.03 5,231.31 5,178.26 2,976.93 -9,171.47 5,977,289.19 11,744.14 69.39 287.69 5,264.99 5,211.94 3,004.22 -9,256.15 5,977,317.92 11,838.80 69.56 288.15 5,298.18 5,245.13 3,031.49 -9,340.50 5,977,346.64 11,933.86 68.90 288.39 5,331.89 5,278.84 3,059.36 -9,424.91 5,977,375.95 12,029.29 68.97 288.16 5,366.19 5,313.14 3,087.28 -9,509.47 5,977,405.32 12,125.02 68.95 288.38 5,400.56 5,347.51 3,115.29 -9,594.31 5,977,434.78 12,219.95 69.04 288.18 5,434.59 5,381.54 3,143.09 -9,678.46 5,977,464.02 12,315.23 68.81 288.44 5,468.85 5,415.80 3,171.02 -9,762.87 5,977,493.39 12,410.20 68.81 288.32 5,503.18 5,450.13 3,198.94 -9,846.90 5,977,522.75 12,505.07 68.90 288.36 5,537.40 5,484.35 3,226.78 -9,930.88 5,977,552.02 12,599.50 69.29 287.89 5,571.10 5,518.05 3,254.22 -10,014.72 5,977,580.90 12,694.89 69.34 287.77 5,604.79 5,551.74 3,281.55 -10,099.68 5,977,609.68 12,789.10 69.21 287.74 5,638.13 5,585.08 3,308.42 -10,183.59 5,977,637.98 12,884.73 69.49 287.63 5,671.86 5,618.81 3,335.60 -10,268.85 5,977,666.62 12,979.94 69.37 287.76 5,705.31 5,652.26 3,362.70 -10,353.77 5,977,695.17 13,072.34 69.17 287.09 5,738.02 5,684.97 3,388.58 -10,436.22 5,977,722.46 13,165.87 68.60 287.28 5,771.71 5,718.66 3,414.35 -10,519.58 5,977,749.66 13,257.52 68.80 287.27 5,805.00 5,751.95 3,439.71 -10,601.12 5,977,776.41 13,350.36 69.09 287.50 5,838.35 5,785.30 3,465.60 -10,683.80 5,977,803.72 13,443.23 68.69 287.47 5,871.80 5,818.75 3,491.63 -10,766.43 5,977,831.16 13,534.29 69.67 287.35 5,904.17 5,851.12 3,517.10 -70,847.65 5,977,858.01 13,628.40 69.48 287.48 5,937.01 5,883.96 3,543.49 -10,931.80 5,977,885.85 13,721.58 68.64 287.69 5,970.31 5,917.26 3,569.78 -11,014.76 5,977,913.56 13,814.56 68.63 287.60 6,004.18 5,951.13 3,596.03 -11,097.27 5,977,941.22 13,905.67 70.10 287.22 6,036.29 5,983.24 3,621.54 -11,178.63 5,977,968.12 13,999.47 69.53 286.54 6,068.66 6,015.67 3,647.10 -11,262.87 5,977,995.12 14,093.68 69.03 285.85 6,101.99 6,048.94 3,671.68 -11,347.49 5,978,021.15 14,186.75 68.37 285.99 6,135.80 6,082.75 3,695.47 -11,430.88 5,978,046.36 14,278.56 69.03 286.90 6,169.15 6,116.10 3,719.68 -11,512.92 5,978,071.98 14,371.08 69.10 287.41 6,202.21 6,149.16 3,745.17 -11,595.48 5,978,098.88 14,463.38 69.02 287.31 6,235.19 6,182.14 3,770.89 -11,677.76 5,978,126.00 14,556.61 69.01 287.30 6,268.58 6,215.53 3,796.78 -11,760.87 5,978,153.32 14,650.58 69.10 287.09 6,302.17 6,249.12 3,822.73 -11,844.71 5,978,180.70 14,743.80 69.30 286.77 6,335.28 6,282.23 3,848.10 -11,928.07 5,978,207.50 14,837.77 69.40 286.23 6,368.42 6,315.37 3,873.08 -12,012.38 5,978,233.91 14,930.36 69.24 286.35 6,401.11 6,348.06 3,897.38 -12,095.53 5,978,259.63 Map Vertical Fasting DLS Section (n) (°~100~) (ft) Survey Taol Name 362,450.24 0.77 6,454.32 MWD+IFR-AK-CAZ-SC t5) 362,365.42 0.31 6,514.48 MWD+IFR-AK-CAZ-SC (5) 362,280.93 0.62 6,574.41 MWD+IFR-AK-CAZ-SC (5) 362,196.31 0.50 6,634.83 MWD+IFR-AK-CAZ-SC (5) 362,111.95 0.93 6,696.15 MWD+IFR-AK-CAZ-SC (5) 362,027.75 0.43 6,757.80 MWD+IFR-AK-CAZ-SC (5) 361,943.88 0.49 6,819.30 MWD+IFR-AK-CAZ-SC (5) 361,859.98 0.73 6,881.34 MWD+IFR-AK-CAZ-SC (5) 361,775.92 0.24 6,943.51 MWD+IFR-AK-CAZ-SC (5) 361,691.58 0.22 7,005.87 MWD+IFR-AK-CAZ-SC (5) 361,607.92 0.22 7,067.75 MWD+IFR-AK-CAZ-SC (5) 361,524.02 0.35 7,129.85 MWD+IFR-AK-CAZ-SC (5) 361,440.48 0.12 7,191.78 MWD+IFR-AK-CAZ-SC (5) 361,356.99 0.10 7,253.63 MWD+IFR-AK-CAZ-SC (5) 361,273.65 0.62 7,315.04 MWD+IFR-AK-CAZ-SC (5) 361,189.18 0.13 7,376.84 MWD+IFR-AK-CAZ-SC (5) 361,105.74 0.14 7,437.78 MWD+IFR-AK-CAZ-SC (5) 361,020.97 0.31 7,499.59 MWD+IFR-AK-CAZ-SC (5) 360,936.54 0.18 7,561.17 MWD+IFR-AK-CAZ-SC (5) 360,854.55 0.71 7,620.57 MWD+IFR-AK-CAZ-SC (5) 360,771.66 0.64 7,680.28 MWD+IFR-AK-CAZ-SC (5) 360,690.57 0.22 7,738.81 MWD+IFR-AK-CAZ-SC (5) 360,608.35 0.39 7,798.33 MWD+IFR-AK-CAZ-SC (5) 360,526.18 0.43 7,857.95 MWD+IFR-AK-CAZ-SC (5) 360,445.43 1.08 7,916.44 MWD+IFR-AK-CAZ-SC (5) 360,361.75 0.24 7,977.05 MWD+IFR-AK-CAZ-SC (5) 360,279.26 0.93 8,037.05 MWD+IFR-AK-CAZ-SC (5) 360,197.21 0.09 8,096.81 MWD+IFR-AK-CAZ-SC (5) 360,116.31 1.66 8,155.41 MWD+IFR-AK-CAZ-SC (5) 360,032.53 0.91 8,215.31 MWD+IFR-AK-CAZ-SC (5) 359,948.35 0.87 8,274.50 MWD+IFR-AK-CAZ-SC (5) 359,865.39 0.72 8,332.43 MWD+IFR-AK-CAZ-SC (5) 359,783.79 1.17 8,390.16 MWD+IFR-AK-CAZ-SC (5) 359,701.68 0.52 8,449.26 MWD+IFR-AK-CAZ-SC (5) 359,619.86 0.13 8,508.45 MWD+IFR-AK-CAZ-SC (5) 359,537.22 0.01 8,568.15 MWD+IFR-AK-CAZ-SC (5) 359,453.84 0.23 8,628.22 MWD+IFR-AK-CAZ-SC (5) 359,370.93 0.39 8,687.58 MWD+IFR-AK-CAZ-SC (5) 359,287.07 0.55 8,746.98 MWD+IFR-AK-CAZ-SC (5) 359,204.36 0.21 8,805.27 MWD+IFR-AK-CAZ-SC (5) 8/17/2009 10:09:58AM Page 6 COMPASS 2003.16 Burld 69 i • C onocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Ina Locai Co-ordinate Refer ence: Well CD2-73 Project: Western North Slope TVD Reference: CD2-73 (15. 6 + 37.45) @ 53.05ft(Doyon 19) Site: CD2 Alpine Pad MD Refere nce: CD2-73 (15. 6 + 37.45) @ 53.05ft(Doyon 19) Weil: CD2 -73 North Reference: True Wellborn: CD2-73P81 Survey Calculation Method: Minimum Curvature Design: CD2-73PB1 - - " batabase: - ?CPA I EDM Production - Survey - I Map Map Vertical MD Inc Azi TVD TVDSS +NI-5 +E/-W Northing Fasting DLS Section Ift1 (~) l~) (ft1 (ft) (ft) Ift) (ft) (ft) (°1100') (ft) Survey Tool Name 15,024.24 68.54 2H6.63 6,434.53 6,381.88 3,522.23 -12,175.5'i 5,978,285.53 359,120.52 0.80 2,864.43 MWD+IFR-AK-CAZ-SC(5~ 15,118.34 68.31 286.92 6,469.53 6,416.48 3,947.49 -12,263.29 5,978,312.62 359,037.49 0.38 8,923.85 MWD+IFR-AK-CAZ-SC (5) 15,211.23 68.78 286.54 6,503.50 6,450.45 3,972.38 -12,346.08 5,978,338.92 358,955.15 0.63 8,982.52 MWD+IFR-AK-CAZ-SC (5) 15,304.08 69.16 286.91 6,536.82 6,483.77 3,997.32 -12,429.08 5,978,365.28 358,872.60 0.55 9,041.32 MWD+IFR-AK-CAZ-SC (5) 15,395.55 69.21 287.42 6,569.33 6,516.28 4,022.55 -12,510.78 5,978,391.91 358,791.36 0.52 9,099.81 MWD+IFR-AK-CAZ-SC (5) 15,489.39 69.65 287.34 6,602.30 6,549.25 4,048.79 -12,594.62 5,978,419.59 358,707.98 0.48 9,160.15 MWD+IFR-AK-CAZ-SC (5) 15,584.11 69.30 287.07 6,635.51 6,582.46 4,075.03 -12,679.36 5,978,447.28 358,623.71 0.46 9,220.88 MWD+IFR-AK-CAZ-SC (5) 15,677.49 69.22 287.11 6,668.58 6,615.53 4,100.70 -12,762.83 5,978,474.37 358,540.70 0.09 9,280.54 MWD+IFR-AK-CAZ-SC (5) 15,770.69 69.07 287.30 6,701.76 6,648.71 4,126.46 -12,846.03 5,978,501.55 358,457.96 0.25 9,340.16 MWD+IFR-AK-CAZ-SC (5) 15,864.33 69.33 286.84 6,735.01 6,681.96 4,152.15 -12,929.71 5,978,528.68 358,374.74 0.54 9,399.94 MWD+IFR-AK-CAZ-SC (5) 15,957.89 69.42 286.53 6,767.97 6,714.92 4,177.29 -13,013.58 5,978,555.25 358,291.32 0.32 9,459.31 MWD+IFR-AK-CAZ-SC (5) 16,051.50 69.60 286.45 6,800.73 6,747.68 4,202.18 -13,097.67 5,978,581.58 358,207.68 0.21 9,518.54 MWD+IFR-AK-CAZ-SC (5) 16,143.94 68.33 286.82 6,833.91 6,780.86 4,226.88 -13,180.33 5,978,607.69 .358,125.46 1.42 9,576.97 MWD+IFR-AK-CAZ-SC (5) 16,236.77 68.69 287.03 6,867.92 6,814.87 4,252.03 -13,262.97 5,978,634.25 358,043.28 0.44 9,635.80 MWD+IFR-AK-CAZ-SC (5) 16,327.53 69.49 286.81 6,900.31 6,847.26 4,276.70 -13,344.08 5,978,660.31 357,962.61 0.91 9,693.53 MWD+IFR-AK-CAZ-SC (5) 16,420.36 68.94 286.59 6,933.26 6,880.21 4,301.64 -13,427.27 5,978,686.67 357,879.93 0.63 9,752.39 MWD+IFR-AK-CAZ-SC (5) 16,513.79 69.15 286.59 6,966.67 6,913.62 4,326.55 -13,510.83 5,978,713.02 357,796.75 0.22 9,811.44 MWD+IFR-AK-CAZ-SC (5) 16,606.64 68.23 286.49 7,000.41 6,947.36 4,351.18 -13,593.75 5,978,739.06 357,714.27 1.00 9,869.92 MWD+IFR-AK-CAZ-SC (5) 16,699.64 68.57 287.94 7,034.65 6,981.60 4,376.77 -13,676.34 5,978,766.06 357,632.14 1.50 9,929.13 MWD+IFR-AK-CAZ-SC (5) 16,793.47 68.09 289.39 7,069.30 7,016.25 4,404.67 -13,758.95 5,978,795.38 357,550.03 1.52 9,990.42 MWD+IFR-AK-CAZ-SC (5) 16,886.79 67.40 290.33 7,104.64 7,051.59 4,434.01 -13,840.18 5,978,826.11 357,469.32 1.19 10,052.40 MWD+IFR-AK-CAZ-SC (5) 16,980.86 67.85 292.48 7,140.45 7,087.40 4,465.76 -13,921.16 5,978,859.24 357,388.90 2.17 10,116.43 MWD+IFR-AK-CAZ-SC (5) 17,072.34 68.05 296.40 7,174.81 7,121.76 4,500.83 -13,998.33 5,978,895.63 357,312.35 3.98 10,181.79 MWD+IFR-AK-CAZ-SC (5) 17,764.14 71.46 298.04 7,206.57 7,153.52 4,540.23 -14,074.90 5,978,936.33 357,236.48 4.08 10,250.77 MWD+IFR-AK-CAZ-SC (5) 17,256.72 74.23 298.05 7,233.88 7,180.83 4,581.82 -14,152.97 5,978,979.25 357,159.14 2.99 10,322.37 MWD+IFR-AK-CAZ-SC (5) 17,348.17 77.54 296.73 7,256.18 7,203.13 4,622.61 -14,231.71 5,979,021.38 357,081.12 3.88 10,393.54 MWD+IFR-AK-CAZ-SC (5) 17,440.45 81.17 295.48 7,273.22 7,220.17 4,662.50 -14,313.13 5,979,062.66 357,000.40 4.15 10,465.09 MWD+IFR-AK-CAZ-SC (5) 17,533.59 84.16 295.45 7,285.11 7,232.06 4,702.22 -14,396.53 5,979,103.80 356,917.71 3.21 10,537.35 MWD+IFR-AK-CAZ-SC (5) 17,625.21 85.59 296.08 7,293.29 7,240.24 4,741.88 -14,478.71 5,979,144.87 356,836.23 1.70 10,609.02 MWD+IFR-AK-CAZ-SC (5) 17,719.95 84.97 296.43 7,301.09 7,248.04 4,783.65 -14,563.38 5,979,188.08 356,752.29 0.75 10,683.68 MWD+IFR-AK-CAZ-SC (5) 17,803.70 85.78 297.91 7,307.84 7,254.79 4,821.77 -14,637.65 5,979,227.46 356,678.70 2.01 10,750.50 MWD+IFR-AK-CAZ-SC (5) 17,830.00 85.78 297.91 7,309.78 7,256.73 4,834.04 -14,660.82 5,979,240.14 356,655.73 0.00 10,771.69 PROJECTED to TD 8/17/2009 10:09:5BAM Page 7 COMPASS 2003.16 Build 69 ConocaPhi~~ips Time Log & Summary WelNiew Web ReAQKing Report Well Name: CD2-73 Rig Name: DOYON 19 Job Type: DRILLING ORIGINAL Rig Accept: 7/22/2009 12:00:00 AM Rig Release: 8/14/2009 12:00:00 AM Ttme Logs Date From To Dur S. Depth E Depth Phase Code Subcode T Comment 1 /04/2009 24 hr summary MIRU f/CD2-468 to CD2-73 -Accept Rig @ 2200 14:00 22:00 8.00 0 0 MIRU MOVE MOB P Move Pit Complex, Ball Mill, Pipe Shed, and Drilling Sub f/CD2-468 to CD2-73 22:00 00:00 2.00 0 0 MIRU MOVE RURD P Connct Rig to High Line Power @ 2200 Hrs -Accept Rig @_2200H_rs - Nippte Up Riser & Connect Service Lines 1 /05/2009 Continue to Nipple Up Surface Riser -Take on Spud Mud - P/U 5" DP f/ Shed (3 stds) -Slip & Cut Drill Line - MU BHA -Upload MWD (Pre -spud during upload) -Fill hole ck for leaks - PT mud lines to 3500 psi -Wash down to 114' S ud in 10:15 hrs. Drilled 13 1/2" hole f/ 114' to 899' MD takin o's eve stand 00:00 02:00 2.00 114 114 SURFA( DRILL RURD P NU surface riser -Install mouse hole 02:00 04:45 2.75 114 114 SURFA( DRILL PULD P PU & std back NM flex DC's & jars - 3 stds 5" DP -Take on s ud mud 04:45 05:00 0.25 114 114 SURFA( RIGMNT SFTY P PJSM on cut & slip drill line 05:00 06:45 1.75 114 114 SURFA( RIGMNT SVRG P Cut & slip 60' drill line -Service TD - celibrate block hei ht 06:45 08:45 2.00 114 114 SURFA( DRILL PULD P MU BHA #1 -bit -motor &MWD 08:45 09:00 0.25 114 114 SURFA( DRILL SFTY P Held Pre-spud meeting (while u loadin MWD 09:00 09:30 0.50 114 114 SURFA( DRILL OTHR P Fill hole & ck for leaks OK - Pressure test mud lines to 3500 psi - OK 09:30 10:15 0.75 114 114 SURFA( DRILL UREM P MU MN flex DC's & Jars f/derrick - establish circ -wash down to 114' 10:15 12:00 1.75 114 196 SURFA( DRILL DDRL P Spud in @ 10:15 hrs. Drilled 13 1/2' hole w/ motor f/ 114' to 196' MD - 196' TVD ADT - .97 hrs WOB - 5/15 k RPM 30 GPM 500 @ 730 psi String wt. PU 100 SO 100 Rot 100 Torque on/off btm.- 4500/3500 ft/Ibs Takin G ro surve s 12:00 00:00 12.00 196 899 SURFA( DRILL DDRL P Drilled 13 1/2" Hole w/ Motor f/ 196' - 899' MD -Taking Single Shot Gyro's Every Stand ADT 6.83, AST 4.21, ART 2.62 480 GPM @ 900 Psi Torque On/Off - 5,500!5,000 @ 50 RPM P/U 125, S/O 122, Rot 125 Pare 1 of 3 • Time Logs__ _-- - --~ --- - Date From To Dur S Deoth E. Depth Phase Code Subco_de T Comment 1 /06/2009 2a hr Summary Drilled 13 1/2" Hole w/ Motor f/ 899' - 2505' MD 00:00 12:00 12.00 899 1,708 SURFA( DRILL DDRL P Drilled 13 1/2" Hole w/ Motor f/ 899' - 1708' MD ADT 6.2, AST 4.07, ART 2.13 600 GPM @ 1330 Psi WOB 15 - 20 Torque On/Off - 7,500/6,000 @ 50 RPM P/U 134, S/O 130, Rot 133 12:00 00:00 12.00 1,708 2,505 SURFA( DRILL DDRL P Drilled 13 1/2" Hole w/ Motor f/ 1708' - 2505' M D ADT 8.53, AST 2.47, ART 6.06 650 GPM @ 1850 Psi WOB 15 - 30 Torque On/Off - 7,500/6,000 @ 50 RPM P/U 134, S/O 125, Rot 129 1 /07/2009 Drill 13 1/2" Surface Hole w/ Motor f/ 2505' - 3688' MD (TD) - 2388 TVD -Circ & Condition Mud for Wiper Trip - OWFF Static - BROOH f/ 3668' - 2551' MD 00:00 12:00 12.00 2,505 3,299 SURFA( DRILL DDRL P Drilled 13 1/2" Hole w/ Motor f/ 2505' - 3299' MD ADT 9.35, AST 1.69, ART 7.66 650 GPM @ 2070 Psi WOB 15 - 30 Torque On/Off - 9,500/6,000 @ 50 RPM P/U 137, S/O 125, Rot 130 12:00 20:30 8.50 3,299 3,668 SURFA( DRILL DDRL P Drilled 13 1/2" Hole w/ Motor f/ 3299' - 3668' MD (TD) - 2388' TVD ADT 7.13, AST .64, ART 6.49 650 GPM @ 2200 Psi WOB 15 - 25 Torque On/Off - 9,000/6,500 @ 60 RPM P/U 137, S/O 125, Rot 132 20:30 21:15 0.75 3,668 3,668 SURFA( DRILL CIRC P Circ & Condition Mud for Wiper Trip 1.5 BU - 700 GPM 2410 Psi 21:15 21:30 0.25 3,668 3,668 SURFA( DRILL OWFF P OWFF (Static) 21:30 00:00 2.50 3,668 2,551 SURFA( DRILL WPRT P Wiper Trip f/ 3668' - 2551' MD - 600 GPM 1780 Psi 1 /08/2009 Continued to BROOH t/ 935' MD - OWFF (Static) - RIH t/ 3593' Then Washed t/ 3668' MD -Circ & Cond Mud for Trip -POOH on TT t/ 903' MD - L/D BHA #1 - R/U and Run 10 3/4" Casing -Lost Partial Returns @ 479, 1531, and 1850' MD -Washed Casing Dwon f/ 1850' - 2300' - RIH U 2976' MD - Cir & Condition Mud Staging Pum s U f/ 3.5 BPM to 5 BPM with Full Returns 00:00 02:45 2.75 2,551 935 SURFA( DRILL WPRT P BROOH f/ 2551' - 935' MD - 600 GPM @ 1700 Psi - 50 RPM / Reduced Pump Rates in Permafrost t/ 400 GPM 860 Psi 02:45 04:15 1.50 935 3,593 SURFA( DRILL WPRT P Blow Down Top Drive - OWFF Static - RIH t/ 3593' MD Pare Z of ~> ~~ _ _ _ Time Logs _ Date From To Dur S. De th E,_D th Phase Code Subcode T Comment 04:15 06:30 2.25 3,593 3,668 SURFA( DRILL OTHR P Wash Down t/ 3668' -Circ & Cond Mud 450 GPM @ 1150 Psi NOTE: Traction Motor on MP2 Failed Casuin Reduced Pum Rates 06:30 06:45 0.25 2,976 SURFA( CASING OWFF P Blow Down Top Drive - OWFF Static 06:45 09:15 2.50 3,668 903 SURFA( DRILL TRIP P POOH on TT t/ 903' MD 09:15 09:30 0.25 903 903 SURFA( DRILL OWFF P OWFF (Static) 09:30 13:00 3.50 903 0 SURFA( DRILL PULD P Stadn Back HWDP & NMFDC's - Read MWD Data & UD BHA #1 13:00 14:30 1.50 0 0 SURFA( CASING RURD P Clean & Clear Rig Floor - R/U U Run 10 3/4" Casin 14:30 19:30 5.00 0 1,531 SURFA( CASING RNCS P RIH w/ 10 3/4" Casin~~t/ 479' MD - CasingTaking Weight -Wash Down t/ 1531' MD 5 BPM @ 240 Psi - Casing Taking Wt. and Partial Loss of Returns 19:30 20:00 0.50 1,531 1,531 SURFA( CASING CIRC P CBU - 4 BPM @ 380 Psi 20:00 22:45 2.75 1,531 2,976 SURFA( CASING RNCS P Continue to RIH f/ 1531' - 1850' MD - Deminished Returns -Established Circ and Wahsed Casing Down f/ 1850' - 2300' MD -Established Circ w! Full Returns & RIH w/ Casin f/ 2300' - 2976' MD w/ No Losses 22:45 00:00 1.25 2,976 2,976 SURFA( CASING CIRC P CBU while Staging Pumps Up f/ 3.5 BPM @ 380 Psi t/ 5 BPM @ 440 Psi - P/U 175, S/O 138 1 /09/2009 Continue to RIH w/ 10 3/4" Casing and Land at 3657' MD -Circ & Condition Mud Lowering YP for Cement Job - Cement Casing by Pumping 485 Bbls 10.7 PPG Lead and 59 Bbls 15.8 PPG Tail -Bumped Plugs w/ 500 Psi - CIP @ 0650 9 Jan 09 -Test Casing t/ 3000 Psi f/ 30 Minutes, Lost 7% - N/D Surface Riser and N/U Casing Head -Run 3 1/2" Kill String t/ 2046' MD -Install TWC & Test to 5000 Psi - N/U Tree and Test U 5000 Psi - R/U and Test Casing w/ Cement Unit U 3500 Psi, Lost 2% -Freeze Protect Well w/ 161 Bbls Diesel - Se BPV -Secure Well - Be in UD 5" DP and HWDP f! Derrick 00:00 01:00 1.00 2,976 3,657 SURFA( CASING RNCS P Continue U Run & Land Surface Casin t/ 3657' MD 01:00 01:30 0.50 3,657 3,657 SURFA( CEMEN- PULD P UD Franks Fill Tool -Blow Down Top Drive - P/U Cement Head 01:30 03:15 1.75 3,657 3,657 SURFA( CEMEN" CIRC P Circ & Condition Mud Lowering YP for Surface Cement Job ~'ag~ 3 of 35 • Time Logs _ __ _ __ Date From To Dur S Depth E. De th ___ Phase Code Subcode T Comment ___ 03:15 07:00 3.75 3,657 3,657 SURFAt CEMEN" CIRC P Cement 10 3/4" Csg as Follows :Rig Pumped 57 bbls WBM w/ Nut Plug as Marker, 33 Bbls Biozan w/Nut Plug, Switched to Dowell and Pumped 5 bbls Water. Pressure Tested Lines to 3,500 Psi. Dropped Btm Plug and Pumped 50 bbls Mud Push @ 10.5 ppg at 4 BPM & 130 Psi -Mixed & Pumped 485 bbls Lead Slurry (ASL) @ 10.7 PPG @ 7.5 BPM @ 485 Psi ("Observed Nut Plug Marker @ Shakers w/ 471 Bbls Lead Pumped then Pumped Down Surge Can) Pumped 59 Bbls of 15.8 PPG Tail Slurry (Class G w/ Additives) @ 5.7 BPM at 595 Psi. Dropped Top Plug w/ 20 bbls Water f/ Dowell. Switched Over to Rig Pumps & Displaced Cmt w/ 321 Bbls 9.6 ppg Brine. Displaced @ 8 BPM for First 305 bbls Then Slowed to 4 BPM @ 660 Psi for 16 Bbls, Bumped Plug w/ 1120 Psi (Pre Bump Pressure 620 Psi) Check float (held OK) CIP @ 0650 Hrs. Had Full Circulation Throughout Job w/ 151 bbls 10.7 PPG Cement Returned to Surface. Reci rocated Pipe While Circulating & Landed casing at the end of L f d t t il l i oss o ue o na a s urry oumo Down Wei ht. 07:00 08:00 1.00 3,657 3,657 SURFAt CASING DHEQ P R/U & Test Casing to 3,000. Psi f/ 30 Minutes -Pressure Dropped 7% Over 30 minute Test 08:00 09:00 1.00 3,657 3,657 SURFA( CEMEN" RURD P UD Cementing Equipment - UD Landin Joint 09:00 10:30 1.50 3,657 0 SURFAt WELCTL NUND P N/D Surface Riser and Adapter Spool 10:30 11:30 1.00 0 0 SURFAt WELCTL NUND P N!U Cassng Head and Test U 1000 Psi 11:30 12:00 0.50 0 0 COMPZ RPCOM PULD P Install Tubing Wear Ring 12:00 13:00 1.00 0 0 COMPZ RPCOM RURD P R/U t/ Run 3 1/2" Kill Strin 13:00 15:30 2.50 0 2,046 COMPZ RPCOM RCST P PJSm -Run 3 1/2" Kill String as Follows: WLEG - 63 Jts of 3 1/2" 9.3# EUE Tubing - XO - 1 Jt 4 1/2" 12.6# IBTM Tubin -Han er 15:30 17:30 2.00 2,046 2,046 COMPZ DRILL OTHR P Install TWC -Test t/ 5000 Psi Failed -Replace TWC and Test to 5000 Psi Good 17:30 19:00 1.50 2,046 2,046 COMPZ DRILL NUND P Nipple Up Tree & Test t/ 5000 Psi Good 19:00 20:00 1.00 2,046 2,046 COMPZ CASING PRTS P R/U and Test Casing t/ 3500 Psi f/ 30 minutes -Lost 2% of Pressure Over 30 Minute Test 20:00 22:00 2.00 2,046 0 COMPZ CASING FRZP P Pump 161 Bbls of Diesel for to Freeze Protect Casing -Blow Down and Ri Down Lines t'ar~~ 4 of 35 • Time Logs_ _ _ Date From To Dur S. De th E. De th Phase Code Subcode _ T Comment _ _ 22:00 23:30 1.50 0 0 COMPZ DRILL OTHR P R/U Lubricator Set BPV and Secure Well 23:30 00:00 0.50 0 0 DEMOB MOVE DMOB P UD 5" DP f/ Derrick and Pre for Move to CD3-305 1 /10/2009 UD 5" Dp, HWDP, and NMFDC's -Clean Pits, Drip Pans, and Sub 00:00 05:00 5.00 0 0 DEMOB MOVE DMOB P UD 34 Stands of 5" DP, 8 Stands of HWDP, and 1 Stand of NMFDC's for Ri Move 05:00 09:00 4.00 0 0 DEMOB MOVE DMOB P Clean Pits & Subs -Release Rig @ 0900 Hours 6/28/2009 ~ ~- Move rig f/ CD(~1-74 to CDt~-73 -spot sub -Mate up pit, motor & pipe shed complexes -Skid floor to drilling osition - Hook u service lines -Tie ri into hi h line ower 06:00 12:00 6.00 3,668 3,668 MIRU MOVE TRNS P Move rig f/CD2-74 to CD2-73 -Spot sub -Mate up pit, motor, & pipe shed complexes -Skid floor to drilling position -Hook up service lines -Tie ri into hi h line ower. 06:00 07:30 1.50 3,668 3,668 COMPZ DRILL OTHR P Acre t ri 1200 hrs. -Pull BPV - RU to displace freeze protect diesel -Take on brine in its 07:30 09:15 1.75 3,668 3,668 COMPZ DRILL PRTS P PJSM -Test hard lines to 500 psi - Displaced freeze protect diesel from well pumping 220 bbls 9.6 ppg brine @ 330 psi -Taking returns to tiger tank 09:15 10:00 0.75 3,668 3,668 COMPZ DRILL PRTS P Test hard lines to 4000 psi -tested 10 3/4" cs to 3500 si for 10 mins.- Blow down hard lines & RD lines 10:00 12:30 2.50 3,668 3,668 SURFA( DRILL NUND P Set TWC - ND tree - NU BOPE, riser & flow line 12:30 13:15 0.75 3,668 3,668 COMPZ DRILL OTHR P Pull TWC - MU landiing jt. -RIH & engage tbg hanger -Back out lock downs -Unseat tbg hanger & pull to ri floor - PU wt. 85 k 13:15 13:30 0.25 3,668 3,668 COMPZ RPCOM SFTY P PJSm on pulling & Ld kill string 13:30 16:30 3.00 3,668 3,668 COMPZ RPCOM TRIP P Pull & LD kill string (1 jt 4 1/2' 12.6# tb & 63 'ts 3 1 /2" 9.3# tb 16:30 17:00 0.50 3,668 3,668 COMPZ RPCOM RURD P RD tbg equipment & clean up rig floor 17:00 18:00 1.00 3,668 3,668 SURFA( DRILL BOPE P RU to test ROPE -grease auto IBOP - Set test plug -fill stack & choke manifold water 6/29/2009 Test BOPE - PU & Std back 155 stds 5" DP -Install WB - MU BHA #2 -RIH w/ BHA PU 5" DP f/shed (33 'ts 00:00 04:15 4.25 3,668 3,668 SURFA( DRILL BOPE P Test BOPE - Hydril to 250 & 2500 psi -Pipe rams blind rams, choke & kill line valves, choke manifold valves, TD IBOP's -floor safety & dart valves to 250 & 3500 psi -Performed accumulator closure test - Witnessing of test waived by Chuck Scheve AOGCC - RD & blow down kill & choke lines & choke maniflod i • Time Logs __ Date From To Dur S. De th E. De th Phase Code Subcode _ T Comment 04:15 17:00 12.75 3,668 3,668 SURFA( DRILL PULD P PU & std back 155 stds 5" DP f/ shed 17:00 17:30 0.50 3,668 3,668 SURFA( DRILL OTHR P Install wear bushing 17:30 22:00 4.50 3,668 3,668 SURFA( DRILL PULD P MU BHA # 2 - 9 7/8" PDC - GeoPilot -MWD - Up load MWD - PU NM flex DC's - 3 HWDP - Pressure test Geo-Span -Break in GeoPilot bearin s -Pulse test tools 22:00 23:00 1.00 3,668 3,668 SURFA( DRILL TRIP P RIH w/ BHA #2 - PU jars & 14 jts HWDP - 1 jt DP -Ghost reamer - 33 'ts DP -Ghost reamer - to 1883' 23:00 00:00 1.00 3,668 3,668 SURFAt DRILL TRIP P Cont. RIH f/ 1883' to to 2360' - Pickin u 5" DP f/ i e shed 6/30/2009 RIH w/ BHA #2 to 3401' - S&C dril line -Wash down f/ 3401' to 3460' -Clean out shoe track - Dril 20' new hole for FIT -Circ & Perform FIT/LOT to 16.0 ppg EMW -Change well over to 9.6 ppg LSND -Drill 9 7/8' hole f/ 3688' to 5005' 00:00 00:30 0.50 2,360 3,401 SURFA( DRILL TRIP P Cont. RIH f/ 2,360' to to 3,401' - Pickin u 5" DP f/ i e shed 00:30 01:45 1.25 3,401 3,401 SURFA( RIGMNT SLPC P PJSM -Cut and slip drilling line - Service To Drive 01:45 02:30 0.75 3,401 3,476 SURFA( DRILL COCF P Wash and ream from 3,401' to 3,460' - clean out Cement to wiper plugs (A)_ 3 574' - 700 gpm / 2080 psi / 60 rpm 8K for ue 02:30 08:45 6.25 3,476 3,668 SURFA( CEMEN" DRLG P Drill out Cement wiper plugs, float collar @ 3,537', Cement, Shoe @ 3,657', Rat hole to 3,668' - 700 gpm 2080 si / 60 r m 08:45 09:15 0.50 3,668 3,688 SURFA( DRILL DDRL P Drill 20' of new hole to 3,691' 09:15 09:45 0.50 3,688 3,688 SURFA( DRILL CIRC P Displace well to 9.6 ppg LSND mud - Circhole clean for LOT - 700 gpm / 1410 psi / 60 rpm -flow check well, static 09:45 10:45 1.00 3,688 3,688 SURFA( CEMEN" LOT P PJSM - RU and perform LOT to 16.0 - RD down and blow down lines 10:45 11:15 0.50 3,688 3,688 INTRM1 DRILL REAM P Wash and ream from 3,591' to 3,688' -worked bit across shoe several times due to tight spot @ shoe - 800 m/1740 si/60r m 11:15 12:00 0.75 3,688 3,701 INTRM1 DRILL DDRL P Directional Drill 9-7/8" hole w/ 7600 GeoPilot f/ 3,688' to 3,701' MD 2,376' TVD ADT= 0.34 hrs. ECD- 10.04 ppg Footage - 13' WOB 10l15K 60 RPM, 800 gpm @ 1410 psi PUW 150K SOW 110K Rot Wt. 125K Tor ue on/off 18K / 15.5K lane 8 of 3~ Time Logs ___ !. __ ____ Date Ffom To Dur S. Depth E. De th Phase Code Subcode T Comment _ ___ _ 12:00 00:00 12.00 3,701 5,005 INTRM1 DRILL DDRL P Drille 9 7/8" hole w/ GP f/ 3701' to 5005' MD 2866' TVD ADT- 7.34 hrs ECD - 10.56 ppg Footage - 1304' WOB 5 k RPM 170 GPM 800 @ 2500 psi String wt. PU 153 SO 120 ROT 135 Torque on/off btm.-10,000/8,000 ft/Ibs 7/01 /2009 Drilled 9 7/8" hole w/ GP f/ 5005' to 7585' 00:00 12:00 12.00 5,005 6,193 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ GP f/ 5,005' to 6,193' MD 3,288' TVD ADT- 7.85 hrs ECD - 10.72 ppg Footage - 1188' WOB 8/12 k RPM 160 GPM 800 @ 2850 psi String wt. PU 160 SO 115 ROT 138 Torque on/off btm.- 11,500/10,500 ft/Ibs 12:00 00:00 12.00 6,193 7,585 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ GP f/ 6193' to 7585' MD 3796' ND ATD- 7.77 hrs ECD- 10.78 ppg Footage - 1392' WOB 5/15 k RPM 170 GPM 800 @ 2980 psi String wt. PU 167 SO 132 ROT 145 Torque on/off btm.-11,000/8,500 ft/Ibs 7/02/2009 Drilled 9 7/8" hole w/ GP f/ 7585' to 10724' 00:00 12:00 12.00 7,585 9,012 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ GP f/ 7,585' to 9,012' MD 4,289' TVD ADT- 6.75 hrs ECD- 10.66 ppg Footage - 1,427' WOB 10/18 k RPM 170 GPM 800 @ 3010 psi String wt. PU 180 SO 140 ROT 157 Torque on/off btm.- 12,000/8,000 ft/Ibs 12:00 00:00 12.00 9,012 10,724 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ GP f/9012' to 10,724' MD 4883' TVD ADT - 7.20 hrs ECD - 10.73 ppg Footage - 1712' WOB 10/30 k RPM 170 GPM 800 @ 2860 psi String wt. PU 205 SO 145 ROT 167 Torque on/off btm.-15,500/10.000 ft/Ibs 7/03/2009 Drilled 9 7/8" hole w/ GP f/ 10,724' to 13,765' ~~_ P;~ge 7 of 35 Time Logs_ _ __ Date From To Dur S. De th E. Depth Pha e Code Subcode T Comment 00:00 12:00 12.00 10,724 12,341 I NTRMI DRILL DDRL P Drilled 9 7/8" hole w/ GP (/10,724' to 12,341' MD 5,478' TVD ADT - 7.19 hrs ECD - 10.98 ppg Footage - 1617' WOB 20/25 k RPM 170 GPM 800 @ 3130 psi String wt. PU 230 SO 150 ROT 180 Torque on/off btm.-18,500/12.500 fUlbs 12:00 00:00 12.00 12,341 13,765 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ GP f/ 12,341' to 13,765' MD 5986' TVD ADT 6.74 hrs ECD - 10.65 ppg Footage - 1424' WOB 20/25 k RPM 170 GPM 800 @ 3130 psi String wt. PU 240 SO 152 ROT 195 Torque on/off btm. - 19,000/15,000 ft/Ibs 7/04!2009 Drilled 9 7/8" hole w/GP f/ 13,765' to 16,820' 00:00 12:00 12.00 13,765 15,383 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ GP f/ 13,765' to 15,383' MD 6,567' TVD ADT 6.83 hrs ECD - 10.73 ppg Footage - 1618' WOB 20/25 k RPM 170 GPM 800 @ 3350 psi String wt. PU 260 SO 160 ROT 200 Torque on/off btm. - 22,000/15,000 ft/Ibs 12:00 00:00 12.00 15,383 16,820 INTRM1 DRILL DDRL P Drilled 9 7/8' hole w/ GP f/ 15,383' to 16,820' MD 7080' TVD ADT.- 7.29 hrs. ECD - 10.94 ppg Footage - 1437' WOB 24 k RPM 150 GPM 780 @ 3650 psi String wt. PU 290 SO 162 ROT 224 Torque on/off btm.- 21,000/18,500 ft/Ibs 7!05/2009 Drilled 9 7/8' hole w/ GP f/ 16,820' to 17,830' -Circ 3 X btms up @ 780 gpm @ 3550 psi -Wiper trip to top of HZR -Flow ck Static - RIH f/ 16,354' to 17,746' -Worked thruogh tight spot @ 17341' -Wash down to 17,8320' -Circ & bum mud wt. to 10.2 - S of WBS/CLP in drillstrin 00:00 12:00 12.00 16,820 17,830 INTRM1 DRILL DDRL P Drilled 9 7/8' hole w/ GP f! 16,820' to 17.830' MD 7309' TVD ADT.- 8.20 hrs. ECD - 10.68 ppg Footage - 1010' WOB 18/25 k RPM 150 GPM 780 @ 3710 psi String wt. PU 303 SO 155 ROT 214 Torque on/off btm.- 22,000/19,500 ft/Ibs Page S of 3~ Time_Logs ~ _ _ _ __. Date From To Dur S De th E. De th Phase Code Subcode T Comment 12:00 14:45 2.75 17,830 17,830 I NTRM1 DRILL CIRC P CBU - 780 gpm / 3550 psi ! 150 rpm -Mud wt. in 9.8 ppg /mud wt. out 9.9 ppg -Flow check well, mud in annulus aired up with slight flow - CBU - 780 gpm / 3650 psi / 150 rpm -Mud wt. in 9.9 ppg -Mud wt. out 9.9 ppg - No chloride increase observed in mud 14:45 15:15 0.50 17,830 17,830 INTRM1 DRILL OWFF P Flow check well -observed slight flow initially, decreasing with time - Well static in 18 minutes -continued to observe well -for 8 minutes static 15:15 16:45 1.50 17,830 17,653 INTRMI DRILL CIRC P CBU - 780 gpm / 3650 psi / 150 gpm -stood back 2 stands to 17,653' 16:45 19:15 2.50 17,653 16,354 INTRM1 DRILL WPRT P BROOH f/ 17,653' to 16,354' w/ pump @ 700 gpm @ 3090 psi w/ 150 m -tor ue 19.5 k ft/Ibs 19:15 20:30 1.25 16,354 17,746 INTRM1 DRILL TRIP P Flow ck -well static - RIH f/ 16,354' to 17,746' - PU wt. 295 SO wt 150 - Worked through tight spot @ 17,341' w/ um s & rota 20:30 23:00 2.50 17,746 17,830 INTRM1 DRILL CIRC P MU TD -Wash precautionary wash & ream f/ 17,746' 17,830' - Circ and bump mud wt to 10.2 ppg - 700 gpm @ 3290 psi w/ 140 rpm - 19 k ft/Ibs for ue 23:00 00:00 1.00 17,830 17,830 INTRM1 DRILL CIRC P Flow ck. well static --Spot WBS & CL pills in drill string - 420 gpm @ 1410 psi w/ 125 rpm - 18.5 k ft/Ibs. torque - ECD - 10.83 7/06/2009 POOH spotting WBS &Lube pills to 16,341' - POOh w/ pump f/ 16,341' to 15,423' -POOH on TTf/ 15,423' to 3781' -Pump hi viis sweep & lower YP -POOH on TT f/ 3781' to 2069' -Circ btms up @ 2069' -Cont. POOH on TT f/ 2069' to 173' - LD NM DC's & BHA - RU to run 7 5/8" cs . PJSM on runnin cs 00:00 02:00 2.00 17,830 16,341 INTRM1 DRILL TRIP P POOH s ottin WBS and Lube pills into open hole from 17,830' to 16,341' -3b ml480 si/120r m 02:00 03:15 1.25 16,341 15,423 INTRMI DRILL TRIP P BROOH from 16,341' to 15,423' - 600 gpm ! 2340 psi / 125 rpm -Flow check well, static 03:15 12:00 8.75 15,423 3,781 INTRM1 DRILL TRIP P POOH on elevators from 15,423' to 3,781' - PUW 148K SOW 117K - Wiped tight spots at 10,450' and several from 8,700' to 7,700' 12:00 12:45 0.75 3,781 3,591 INTRM1 DRILL CIRC P Backreamed two stands from from 3,781' to 3,591' - 800 gpm / 2440 psi / 120 rpm (reduced rpm to 80 with bha in casing) spotted 130 bbls of 12 yp mud in casing annulus above bit 12:45 14:30 1.75 3,591 2,069 INTRM1 DRILL TRIP P Flow check well, static POOH on elevators from 3,591' to 2,069' - began reducing pulling speed to avoid swabbin f/ 2,355' F'ay~a 9 a# 35 _Time Logs __ __ Date f=rom To Dur S De th E. De th Phase Code Subcode T Comment 14:30 15:00 0.50 2,069 2,069 INTRM1 DRILL CIRC T CBU - 800 gpm / 2240 psi / 80 rpm - Blow down TD & GeoSpan - Observed slight amount of small cuttin back across shakers 15:00 17:00 2.00 2,069 173 INTRMI DRILL TRIP P Cont. POOH on TT f/ 2069' to 173' - LDGhost reamers -Flow ck @ HWDP -well static 17:00 17:45 0.75 173 80 INTRM1 DRILL PULD P LD NM flex DC's 17:45 19:45 2.00 80 0 INTRM1 DRILL PULD P Plug into MWD & down load -Pull up & break bit & service GP while down loading MWD - LD MWD & Geo Pilot -Clear tools f/ ri floor 19:45 20:00 0.25 0 0 INTRM1 DRILL SFTY P PJSM on changing rams 20:00 21:00 1.00 0 0 INTRM1 CASING RURD P Chan a to VBR to 7 5/8" -Chan e TD saver sub to XT-39 21:00 22:30 1.50 0 0 INTRM1 CASING RURD P Pull wear bushing -Set test plug - Test 7 5/8" pipe rams to 250 & 3500 psi -Pull test plug & set thin wall wear bushin - LD short bales 22:30 00:00 1.50 0 0 INTRM1 CASING RURD P PJSM - RU casing equipment & fill u tool -PJSM on runnin cs 7/07/2009 Finish circ casing volume @ 4285' . -Cont. RIH f/ 4285' to 16,206' (380 jts total in hole of 417 to run) Circ & condition 8520' & 12,789' 00:00 05:30 5.50 0 4,285 INTRM1 CASING RNCS P Ran 7 5/8" 29.7# L-80 BTCM casing as follows: Float shoe (Ray Oil Tools silver bullet) 2 jts csg -Float collar (Halliburton super seal II) - 1 jt csg - Halliburton Baffle collar - 1 jt. csg( all connections made up w/ BakerLoc - filled pipe & checked floats) Cont. to RIH with 7 5/8" csg to 4285' (100 jts total PU wt. 153 k SO wt. 123 k 05:30 06:30 1.00 4,285 4,285 INTRM1 CASING CIRC P Est. circ and circ btms up @ 4285', Staged pump rate up to 6 bbls/min. @ 440 psi - PU wt. 150 k SO wt. 125 k 06:30 10:45 4.25 4,285 8,520 INTRM1 CASING RNCS P Cont. RIH with 7 5/8" csg from 4285' to 8520' (200 jts) total - PU wt. 222 k SO wt. 132 k 10:45 12:00 1.25 8,520 8,520 INTRM1 CASING CIRC P Est. circ and circ btms up @ 8520', Staged pump rate up to 6 bbls/min @710 psi-PUwt.210kSOwt. 130 k 12:00 17:00 5.00 8,520 12,789 INTRM1 CASING RNCS P Cont. RIH with 7 5!8" csg from 8520' to 12,789' (300 jts) total - PU wt. 325 k SO wt. 138 k 17:00 19:15 2.25 12,789 12,789 INTRMI CASING CIRC P Est. circ and circ btms up @ 12,789', Staged pump rate up to 6 bbls/min @ 640 psi - PU wt. 285 k SO wt. 140 19:15 00:00 4.75 12,789 16,206 INTRM1 CASING RNCS P Cont. RIH with 7 5/8" csg from 12,789' to 16,206' (380 jts) total - PU wt. 410 k SO wt. 160 k Page 10 of 35 ~ ~ Time Logs _ _ _ _ Date From__ To Dur S. Depth E. Depth Phase Code _ Su6code T Comment _ _ 7/08/2009 24 hr Summary Circ & cond. @ 16,206' (380 jts of 417 jts to run in hole) -Cont. RIH w/ 7 5/8" csg f/ 16,206' to 17,176' (403 jts. in hole) String took wt @ 17,176' - f/ 160k on prior jt to 112 k -Work pipe -Attempt to circ -packing off - Work i e & establish circ 2.8 bbls/min 620 si 00:00 01:45 1.75 16,206 16,206 I NTRM1 CASING CIRC P Circ btms up @ 16,206' -Staged pump rate to 6 bbls/min @ 800 psi PU wt.410 k SO wt. 160 k 01:45 03:15 1.50 16,206 16,206 INTRMI CASING RNCS P Cont. to RIH w/ 7 518" 29.7# L-80 BTCM csg f! 16,206' to 17,176' (403 jts in hole) string took wt. @ 17,176' - 112 k 03:15 12:00 8.75 16,206 17,176 INTRM1 CASING OTHR T Work ti ht hole -pulling 475 k - attempt to circ -hole ackin off - Cont. working pipe unable to pass 17,176' Unable to ull free 12:00 00:00 12.00 17,176 17,176 INTRM1 CASING OTHR T Cont. work stuck pipe -Established circ & staged pump up to 2.8 bbls/min @ 620 psi. (Previous pressure 800 psi @ 6 BPM at last circ point.) Hole packing off when reciprocating casing. Pull to 515k max, no movement. Maintain as .__.-- much flow rate as ossible and work r stuck casin 7/09/2009 Circ & work pipe - RU scffolding for working above floor -Prep to begin pipe recovery - RU cementers - Cmt. 7 5/8" cs . - O en sta a collar -Circ btms u - RU E line for casin cut - RIH w/ tools - 00:00 07:00 7.00 17,176 17,176 INTRM1 CASING OTHR T Cont. to work stuck csg &circ @ 4.5 bbls/min @ 530 psi -pulling to 495 k & slacking off to 95 k - No pipe movement. Decision made to cut casin with Halliburton RTC tool. Note: Rig up scaffolding on rig floor to work above ri floor to RU wirleline 07:00 08:30 1.50 17,176 17,176 INTRM1 CASING RURD T PJSM- RD fill up tool 08:30 10:00 1.50 17,176 17,176 INTRM1 FISH ELNE T PJSM - Prep to RU Halliburton E line -Consult with town staff on plan PP ~ _~~ forward. Unable to get cutter past stage collar dur to ID restriction, ID of stage collar 4.93", OD of RTC 4.95" . Plan to cement bottom part of casing a and cut casin above sta a collar. 10:00 14:15 4.25 17,176 17,176 INTRM1 CEMEN" CMNT - cement ead lines- Circfor cement job -Stage pump up f/ 1 bbl/min @ 230 psi to 4.5 bbls/min 500 si 14:15 14:30 0.25 17,176 17,176 INTRM1 CEMEN 'CMNT T PJSM on cement job Page 11 cif 36 • Time Logs - _ __ Date From To Dur S De th E. Depth Phase Gode Subcode T Comment _ 14:30 18:15 3.75 17,176 17,176 I NTRM1 CEMEN" CMNT T Cement 7 5/8" casing as follows: Drop btm plug - Pumped 20 bbls CW-100 -Test lines to 4000 psi - Pumped 20 bbls Mud Push @ 13.0 ppg -Load top plug -Mixed & um ed 38 bbls Class G w/additives) 15.8 - Dro to plug w/ 20 bbls water f/ Dowell - Switch to rig pump @ displace cmt w/ 10.2 ppg LSND mud @ 4.5 bbls/min @ 450 psi for first 690 bbls -slowed pump to 3 bbls/min for last 71 bbls @ 560 psi -pressure prior to bumping plug 623 psi - bum_ ped plug w/ 1200 psi -Checked floats OK - CIP @ 1800 hrs. - Calc top of cmt 16,600' -Cement job was to P&A lower art of hole rior to cuttin casin 18:15 19:45 1.50 17,176 17,176 INTRM1 CEMEN" CIRC T Pressure u on casin to 34_50 psi to ollar ~ 8300' - Circ as . Btms up + @ 6 bbls/min @ 350 psi - Mud wt. 10.2 in & out 19:45 20:00 0.25 17,176 17,176 INTRM1 CEMEN" SFTY T PJSM on RD cement head 20:00 20:45 0.75 17,176 17,176 INTRM1 CEMEN" RURD T RD cement head & lines 20:45 21:00 0.25 17,176 17,176 INTRM1 FISH SFTY T PJSM on rigging up Haliburton E line 21:00 23:00 2.00 17,176 17,176 INTRM1 FISH ELOG T RU Halliburton E line to plasma cut 7 5/8' casin - RIH to 400' -CCL uestionable 23:00 00:00 1.00 17,176 17,176 INTRM1 FISH ELOG T POOH w/ E Tine -Trouble shoot CCL -working on surface -RIH - to 400' - CCL still uestionable - 7/10/2009 Change CCL tool -RIH tools stopped @ 3600' -Try to pump down - No Go -POOH & add wieght bar - RIH w/ pump to cutting depth @ 8220' -Fire csg cutter (80k tension on string) POOH - RD WL - RU & Attempt to ull cs free -worked i e no movement - RU & Set P & A lu # 2 - WOC - RD cmt head 00:00 00:30 0.50 17,176 17,176 INTRM1 FISH ELNE T POOH w! ELine -Change CCI - 00:30 01:45 1.25 17,176 17,176 INTRM1 FISH ELNE T RIH w/ E line & csg cutter to 3600' - tools sto ed 01:45 02:45 1.00 17,176 17,176 INTRMI FISH ELNE T Attempt to pump tools down f/ 3600' Stage pump up to 8 bbls/min @ 620 psi -tool string still would not go down 02:45 03:45 1.00 17,176 17,176 INTRM1 FISH ELNE T POOH w/wire) line & added another wei ht bar 80 Ibs 03:45 06:00 2.25 17,176 17,176 INTRM1 FISH ELNE T RIH w/wireline & tools - w/ pump @ 4 bbls/min 290 si to 8350' 06:00 08:15 2.25 17,176 17,176 INTRMI FISH CPBO T Pul- u & et cs cutter on depth @ 8220' -Fire cutter string in tension 300k on weight indicator P/U weight at cut depth 220k)- POOH w! wireline & tools -Monitor well on TT 08:15 08:30 0.25 17,176 17,176 INTRM1 FISH CIRC T RD wireline - MU circ swedge - Ru to ull cs P~r~e '! ~ of ~5 Tirne Logs ___ __ _ _ -- ~I Date From To Dur S. De th E. Depth Phase Code Subcode T Comment _ _ _ 08:30 12:00 3.50 17,176 17,176 I NTRM1 FISH CUTP T Attempt to pull csg free - PU to 475 k - SO tp 120 k - No pipe movement -Circ @ 5 bbls/min @ 300 psi - Lower mud wt. to 9.8 12:00 14:30 2.50 17,176 17,176 I NTRMI FISH CUTP T Cont. to work stuck csg while circ - PUto500kSOto125k 14:30 14:45 0.25 17,176 17,176 I NTRM1 CEMEN" SFTY T PJSM on RU Cmt head 14:45 15:30 0.75 17,176 17,176 I NTRM1 CEMEN" PLUG T RD circ swedge - Ru cement head & lines -Establish circ -circ for cmt 'ob -Circ thru sta a collar 8300' 15:30 15:45 0.25 17,176 17,176 I NTRM1 CEMEN' SFTY T PJSM on cmtjob 15:45 17:15 1.50 17,176 17,176 I NTRM1 CEMEN" PLUG T Cement 7 5/8" 2nd sta a -as follows: Pumped 20 bbls CW-100 - Mixed & pumped 38 bbls -Class G w/ additives @ 15.8 ppg -dropped top plug w/ 20 bbls water f/ Dowell - Switched to rig pumps & displaced cmt w/ 9.8 ppg mud to 8137' Inside 7 5/8' casing w/ 31 bbls cmt in 7 5/8" x 9 7/8' annulus to 7491' Calc. top - CIP @ 1710 hrs. -Shut in cmt head - Cementjob was pumped through stage collar @ 8300' - Didn= t bump on stage collar (did not pum lu ast cut 8220' 17:15 23:15 6.00 17,176 17,176 INTRMI CEMEN" WOC T Wait onCmt 23:15 00:00 0.75 17,176 17,176 INTRM1 CEMEN" RURD T Open valve to bleed off pressure (No ressure RD cmt head 7/11 /2009 RU WL -RIH w/ WL & csg cutter -Cut csg @ 3919' (had 65k tension on string)- POOH w/ WL & RD - RU to circ -Est. circ -Pull on csg -work pipe stil unable to pull - RU WL -RIH @ cut csg @ 3865' (had 100k tension on string) -POOH & RD WL -Est. circ -Pull &circ csg up to 3845' - RD scaffolding - LD WL toots & cmt head -Pump dry job -Pull csg to 10 3/4" shoe -Change out 350 T elevators to 150 T side doors -Pull & LD cs 191 'ts & 6.25' cut-o Measure i e To of Stub 3870' RD cs a ui ment -Pull thin wall WB 00:00 04:00 4.00 17,176 17,176 INTRM1 FISH ELNE T PJSM on RU wireline - RU Halliburton wireline - RIH w/ CCI & csg cutter - ck. depth w/ CCI -Cut cs 3919' RKB -POOH w/ WL & tools - RD WL Note: 215 k on weight indicator before setting the casing in slips. P/U at this depth tripping was 150k. 65 k over ulI on strin . 04:00 08:30 4.50 17,176 17,176 INTRM1 FISH CUTP T RU circ swedge &circ hose - Establish Circ thru cut 3919' - Attempt to pull Csq free -Worked pipe to 415 k &circ aC~ 8 bbls/min - Unable to ull cs free - A ears to have artial cut as cir ul io ' ossibte. ~arJe 13 of 3~ ~~ - Time Logs Date From _ To Dur _ S Depth E. De th Phase ~_e Subcode_ T .Comment 08:30 11:00 2.50 17,176 17,176 I NTRM1 FISH ELNE T RU WL & tools -RIH - ck depths w/ CCL - Cut csg @ 3870' -Had positive i ndication surface of cut -POOH w/ WL & tools - RD WL Note: string was set at 250k prior to cut (100k overpull) Casing up wt after cut was 150k on wei ht indicator. 11:00 13:00 2.00 17,176 17,176 I NTRM1 FISH CIRC T MU cmt line -establish circ -Pull & circ out 1 jt. 3845' @ 2 bbls/min @ 70 psi -Circ while RD scaffolding - LD remove scaffolding f/ rig floor & LD WL equipment - Cmt head - PU side door elevators 13:00 13:15 0.25 17,176 17,176 INTRM1 FISH SFTY T PJSM on pulling csg 13:15 14:15 1.00 17,176 17,176 INTRM1 FISH PULL T PUII & LD 7 5/8" csg f/ 3865' to 3657' 10 3/4' cs 14:15 15:00 0.75 17,176 17,176 INTRM1 FISH RURD T RD 350 Televators - LD long bales - PU short bales & 150 T side door elevators 15:00 15:15 0.25 17,176 17,176 INTRMI FISH CIRC T Est. circ & pump 35 bbl dry job 15:15 22:30 7.25 17,176 17,176 INTRM1 FISH PULL T Pull & LD 7 5/8" csg -monitoring well on TT - LD total 91 jts. & 6.25' cut-off -Strapped csg -Top of 7 5/8" stub 3870' RKB 22:30 00:00 1.50 17,176 17,176 INTRMI FISH RURD T RD csg equipment -Pull thin wall wear bushin 7/12/2009 Cut & slip DI -Change upper pipe rams & test - MU cmt striger & RIH on 5" DP to 4257' -circ & spot Hi-vis gel pill -Pull to 4067' Set P&A / KOP plug w/ 59 bbls - 17.0 ppg G cmt.- Calc top @ 3465' -POOH to 3465' - Circ & change over to 9.8 ppg brine -POOH -Run 5" Dp for kill string -Pull WB - MU tbg hanger & land kill strin 2039' 00:00 00:15 0.25 17,176 3,870 INTRMI FISH SFTY T PJSM -Cutting & slipping drill line 00:15 01:30 1.25 3,870 3,870 INTRM1 FISH OTHR T Cut & slip drill line 120' -Service TD & drawworks 01:30 04:45 3.25 3,870 3,870 INTRM1 FISH OTHR T Chan a to rams f/ 7 518" to 3 1/2" x 6" VBR -Test w/ 5" & 3 1!2" test jts. - ull test lu -install wear bushin 04:45 09:00 4.25 0 4,257 INTRM1 CEMEN" TRIP PJSM - RU to run 3 1/2" tbg stinger for cement plug - PU & run 32 jts. 3 1/2"9.3#EUEtb to 997'-MUXO- PU 1 std5"DPto1088'-MUTD& circ tbg volume @ 5 bbls/min @ 5 bbls/min @ 60 psi - RIH f/ 1088' to 4257' 09:00 10:15 1.25 4,257 4,257 INTRM1 CEMEN " CIRC T Circ btms up & spot hi-vis gel pill f/ 4257' to 4067' @ 7 bbls/min @ 250 si 10:15 10:45 0.50 4,257 4,067 INTRM1 CEMEN " TRIP T Pull up to 4067' - RU to spot cement lu 10:45 11:30 0.75 4,067 4,067 INTRM1 CEMEN " PLUG T Circ btms up @ 7 bbls/min @ 400 si 11:30 12:00 0.50 4,067 4,067 INTRM1 CEMEN " SFTY T Held PJSM w/ crew & cementers on settin cmt lu Paga 14 of 35 J Time Lomas _ _ _ - From T~ Dur _ S Depth E. De th Date Phase Code Subcode T Comment __ 12:00 12:30 0.50 4,067 4,067 I NTRM1 CEMEN' CMNT T Sot P&A / KOP as follows: w/ 3, 1/2" tbg stinger @ 4067' -Pumped 20 bbls ahead -Mixed & pumped 59 bbls (328 sxs) Class G w/ additives @ 17.0 ppg -Displaced to equialize - Calc to of cmt 3465' 12:30 13:15 0.75 4,067 3,465 I NTRM1 CEMEN' TRIP T POOH f/ 4067' to 3465' 13:15 15:00 1.75 3,465 3,465 I NTRM1 CEMEN" CIRC T Circ btms up + 15:00 17:00 2.00 3,465 3,465 I NTRM1 CEMEN' CIRC T Displace hole over to 9.8 ppg brine 17:00 18:15 1.25 3,465 997 I NTRMI CEMEN" TRIP T POOH f/ 3450' to 997' 18:15 18:30 0.25 997 997 I NTRM1 CEMEN" TRIP T Change elevators to 3 1/2" 7 RU tbg ton s 18:30 20:30 2.00 997 0 I NTRM1 CEMEN" PULD T PJSM -Pull & LD 3 1/2" tbg stin er 32 ~ts & mule shoe 20:30 21:00 0.50 0 0 INTRM1 CEMEN" RURD T Change elevators to 5" - LD tbg e ui ment 21:00 21:30 0.50 0 1,997 SURPRI RPCOM RCST T RIH w/ 21 stds 5" DP 1997' 21:30 21:45 0.25 1,997 1,997 SURPRI RPCOM SFTY T PJSM on pulling wear bushing 21:45 00:00 2.25 1,997 2,039 SURPRI RPCOM OTHR T MU XO's & wear bushing pulling tool - MU landing jt B - RI H w/ pulling tool engage WB & POOH - LD WB - MU tbg hanger & land kill string w/ tail 2039' Kill string -Mule shoe (5" DP) 21 stds 5" DP - XO (4 1/2" IF to 4" XT-39) XO (4" XT-39 to 4 1 /2" I BT) - FMC tbg hanger w/ elastomer seals w/shoe 2009' RKB 7/13/2009 Test hanger seals -Flush BOP stack -Remove ram blocks -set back BOP stack - NU & test tree -Pull TWC & istall BPV -secure well - LD 5" DP 00:00 00:45 0.75 2,039 2,039 SURPRI DRILL NUND T RU & test tbg hanger seals to 5000 si OK - RD 00:45 02:00 1.25 2,039 2,039 SURPRI DRILL NUND T RU stack washer & flush BOP stack - Blow down lines - RD washer 02:00 07:15 5.25 2,039 2,039 SURPRI DRILL NUND T LD mouse hole - ND riser -Remove ram blocks from BOP's (prep for BOP maintenance) -Remove accumulator hoses -Set back BOP stack 07:15 08:45 1.50 2,039 2,039 SURPRI DRILL NUND T NU tree & test to 5000 psi 08:45 09:30 0.75 2,039 2,039 SURPRI DRILL NUND T Pull TWC & install BPV -Secure well 09:30 00:00 14.50 2,039 2,039 SURPRI MOVE PULD T Install mouse hole - LD 5" DP f/ derrick -Service iron roughneck - Cont. LD 5" DP f/ derrick 7/14/2009 Finish LD DP 00:00 01:15 1.25 0 0 SURPRI MOVE PULD T Continue to L/D from derrickvia mousehole. UD Mousehole. ~~~ ~ F'agc~ 15 of 3 s Time Low _- - -- - - Date From To Dur S Depth E. De th Phase Code_ Subcode T Comment _ . 01:15 06:00 4.75 0 SURPRI MOVE OTHR T Rig up and clean rig for move off well l ine and summer maintenance. VlU ~ `~ ~ !~ v ~ ~ ~~ ~~~ Note: Well suspended, Rig Released 06:00 hours 07/14/2009. 7/22/2009 d'~~ Rig accepted 7/22/09 @ 0000 hrs after maintenance. During maintenance Little Red circulated and heated the 9.8 brine in the well. On 7/15: circ 200 bbls, raising temp f/ 80 deg to 150 deg. On 7/18: circ 200 bbls, raising temp f/ 100 deg to 150 deg. On 7/20: circ 200 bbls, raising temp f/ 105 deg to 150 deg. Pick up/ make up via mouse hole/ stand back in the derrick 18 stands of 5"drill pipe. Adjust brakes and service the rig. Pick up/ make up via mouse hole/ stand back in the derrick 120 stands of 5" drill pipe. ( A total of 138 stands in the derrick). Pre job safety meeting on installing two way check. Check hanger and annulus for ressure. No Pressure. Install two wa check in the han er. Ni le u 13-5/8" 5m BOP stack. 00:00 08:45 8.75 MIRU MOVE OTHR T Rig released from maintenance at 000 hrs 7/22/2009. While on maint, Little Red circulated and heated the 9.8 brine in the well. On 7/15: circ 200 bbls, raising temp f/ 80 deg to 150 deg. On 7/18: circ 200 bbls, raising temp f/ 100 deg to 150 deg. On 7/20: circ 200 bbls, raising temp f/ 105 deg to 150 deg. Load pipe shed w/ 492 joints of 5" drill pipe. Install 4-1/2" saver sub on top drive. Pickup bales and elevators, then install same. 08:45 10:30 1.75 INTRM1 RPCOM PULD T Pick up/make up via mouse hole/ stand back in the derrick 18 stands of 5"drill i e. 10:30 11:30 1.00 INTRM1 RPCOM SVRG T Adjust brakes and service the rig. 11:30 21:45 10.25 INTRM1 RPCOM PULD T Pick up/ make up via mouse hole/ stand back in the derrick 120 stands of 5"drill pipe. (A total of 138 stands in the derrick . 21:45 22:00 0.25 INTRM1 RPCOM SFTY T Pre job safety meeting on installing two wa check. 22:00 22:15 0.25 INTRM1 RPCOM OWFF T Check han er and annulus for pressure. No Pressure. Install two wa ch ck in h n r. 22:15 00:00 1.75 INTRM1 RPCOM NUND T Nipple up 13-5/8" 5m BOP stack. 7/23/2009 Finish nipple up BOPE, test against Blind rams to 5000 psi-OK (tested kill & choke lines to choke and mud line valve). Pull two way check, install landing joint, test casing to 3600 psi (lost 160 psi- good test) against cement plug @ +/- 3465'. Back out lockdown screws, pull hanger to floor, break x-o's, MU running tool f/ wear bushing, install wear bushing, circulate residual diesel out of well, pull out of the hole w/ 21 stands of 5" drill pipe, pull FMC wear bushing, set FMC test plug. Rig up and test BOPE to 250 psi low and 5000 psi high. Witness of test waived by AOGCC inspector Bob Noble. Rig down test equipment. Rig up Sperry Sun Geo Span f/ the GeoPilot. Pick up, then make up BHA #3, upload MWD, continue to make up BHA, test lines to 3400 psi f/ Geo Span. Shallow pulse test MWD- no communication below HCIM. Trouble shoot problem. Pull out to check tools, download MWD, trouble shoot and la down BHA. 00:00 00:30 0.50 INTRM1 RPCOM NUND T Nipple up 13-5/8" 5m BOP stack. 00:30 01:15 0.75 INTRM1 RPCOM RURD T Ri u to bod test 13-5/8" ROPE to the blind rams. F~r1e 16 of 3 i Time Lo~c s _ __ Date From To Dur S. De th E. De th Phase Code Subcode T Comment 01:15 04:45 3.50 INTRMI RPCOM BOPE T Test all flanges up to the blind rams, test choke line to choke manifold on the floor, test kill line to valve on mezzanine. Tested to 2000 psi, bleed off and tighten flange on choke line to stack. Test again to 5000 psi, found leak on top flange of mud cross to BOP, bleed off and tighten same. Pressure to 5000 psi and again flange on mud cross leaking, tighten once more. Pressure test to 5000 si, no leaks, visual-no leaks. bleed off ressure. 04:45 05:00 0.25 INTRM1 RPCOM OTHR T Remove two way check valve. 05:00 06:00 1.00 INTRM1 RPCOM RURD T Pick up and install landing joint. Rig up lines to test 10-3/4" 45.5 ppf L-80 BTCM casing and top of cement estimated at 3465' 2317 TVD . 06:00 07:00 1.00 INTRM1 RPCOM DHEQ T Test the 10-3/4" 45.5 ppf L-80 BTCM casing and top of cement estimated at 3465' 2317' TVD to usin the mud um .Pumping 9.8 ppg brine. Chart test. Lost 160 psi in 30 minutes- ood test. 07:00 08:15 1.25 2,039 2,000 INTRM1 RPCOM PULL T Back out lockdown screws. Pick FMC hanger to rig floor. PU wt 105k. Down wt 105k. Break hanger and crossovers and la down han er. 08:15 09:30 1.25 2,000 2,031 INTRM1 RPCOM OTHR T Make up FMC running tool, then set wear bushin with the kill strin . 09:30 10:30 1.00 2,031 2,031 INTRM1 RPCOM CIRC T Make up the top drive: Circulate diesel out of the annulus. Circulate to balance mud weight. Pumping 7 bpm w/ 60 si. 10:30 11:30 1.00 2,031 0 INTRM1 RPCOM PULL T Pull out of the hole w/the 5"drill pipe, rack drill pipe in the derrick. Monitor well on the tri tank. 11:30 12:00 0.50 0 0 INTRM1 DRILL OTHR T Pull FMC wear bushing. 12:00 13:30 1.50 0 0 INTRM1 DRILL RURD T Set the FMC test plug. Rig up to test BOPE. Fill stack with water. 13:30 13:45 0.25 0 0 INTRM1 DRILL SFTY T Pre job safety meeting on testing BOPE. ~'a~~e 17 ~t 3~ ~ ~ Time Logs _ T Comment Date From To Dur S De th E. De th Phase Code Subco de --- - 13:45 17:00 3.25 0 0 INTRM1 DRILL _ _ BOPE T Test BOPE. Witness of test waived by AOGCC inspector Bob Noble. Tests were charted, high and low tests were 5 minutes each. Gas alarms were tested. Tested w/ 5" test joint.Test upper and lower variable pipe rams (3-1/2" x 6") to 250 psi low and 5000 psi high. Tested annular to 250 psi low and 3500 psi high. Tested blinds to 250 psi low and 5000 psi high. All valves in the choke manifold, kill line and choke line valves were tested, 4" Demco on kill line. Manual and automatic IBOP valves on the top drive were tested. Full opening floor valve and dart valve were tested. Dart valve failed. Rebuilt failed valve and tested later- OK. 17:00 17:30 0.50 0 0 INTRM1 DRILL RURD T Rig down testing equipment. 17:30 18:15 0.75 0 0 INTRM1 CEMEN" PULD T Rig up Sperry Sun Geo Span unit. Bring BHA components to the rig floor. 18:15 19:45 1.50 0 67 INTRM1 CEMEN" PULD T Pick up and make up BHA (Geopilot) er S er Sun directional Driller. 19:45 20:45 1.00 67 67 INTRM1 CEMEN" OTHR T Upload Sperry MWD. 20:45 21:30 0.75 67 364 INTRM1 CEMEN- PULD T Continue to Pick up and make up BHA. Pressure test Geoo Span and mud lines to 3400 si. 21:30 22:15 0.75 364 364 INTRM1 CEMEN" DHEQ T Pulse test. Pumping 550 gpm w/ 860 psi. Pulsing OK, but not showing communication below HCIM. Rotate to break in seals on Geopilot. 22:15 23:00 0.75 328 67 INTRM1 CEMEN" TRIP T PuII out of hole to check MWD tools/ connections. 23:00 00:00 1.00 67 67 INTRM1 CEMEN" OTHR T Download MWD. Trouble shoot BHA. La down BHA. 7/24/2009 Trouble shoot Sperry MWD, change out PWD/DGR, smart stab, EWR-HCIM, upload MWD, make up BHA to 368', shallow pulse test w/ 550 gpm -good test, PU/MU/RIH w/ 4 stands of 5" HWDP, then 26 stands of 5" dp to 3215', pre job safety meeting, slip and cut 60' of 1-3/8" drilling line, service rig and top drive. Run in the hole one stand from the derrick, wash and tag top of cement @ 3463' (pumping 6 bpm w/ 260 psi). Drill cement in the casing to 3657', then cement in open hole to 3691'. Displace 9.8 ppg brine to 9.6 ppg LSND mud. Circulate bottom's up. Perform LOT to 15.2 ppg EMW @ 3691'. Attempt open hole sidetrack from 3691' to 3724' (time drilling), troughing f/ 3718' to 3724', time drilling 3724' to 3745' (6'/hr). Depth @ midnight 3745'. Note: De arture from on final wellbore CD2-73P61 3724'. 00:00 00:30 0.50 67 67 INTRMI CEMEN" O HR T Trouble shoot BHA. Lay down BHA. 00:30 01:00 0.50 67 67 INTRM1 CEMEN" PULD T Change out Sperry PWD/DGR, smart stab, EWR-HCIM. 01:00 01:30 0.50 67 67 INTRM1 CEMEN" OTHR T Upload Sperry Sun MWD 01:30 02:00 0.50 67 368 INTRM1 CEMEN" PULD T Make up nm float collar and a stand of flex drill collar, and a stand of HWDP w/ the 'ars to 368'. 02:00 02:30 0.50 368 368 INTRM1 CEMEN" OTHR T Shallow pulse test MWD w/ 550 gpm w/ 790 si ~ Page 1~ of ~5 I ~® ~ Time Logs _ _ Date From To Dur S De th E. De th Comment Phase Code Subcode T 02:30 05:00 2.50 368 3,215 INTRM1 CEMEN" PULD T _ Pick up from the pipe shed 4 stands of 5" HWDP, then 26 stands of 5" drill pipe (rabbit to 2.34"). Run in the hole to 3215' 05:00 05:15 0.25 3,215 3,215 INTRMI CEMEN- SFTY T Pre job safety meeting on slip and cut drillin line. 05:15 06:30 1.25 3,215 3,215 INTRM1 CEMEN" SLPC T Slip and cut 60' of 1-3/8" drilling line. Reset crown o matic. 06:30 07:15 0.75 3,215 3,215 INTRM1 CEMEN" SVRG T Service rig and top drive. Calibrate Totco de th trackin . 07:15 08:00 0.75 3,215 3,463 INTRM1 CEMEN" WASH T Run in the hole one stand of 5"drill pipe from the derrick to 3310', make a top drive connection and wash to to to of cement at 3463'. Pumping. 6 b m w/ 260 si. 08:00 10:00 2.00 3,463 3,691 INTRM1 CEMEN" DRLG T Drill cement from 3463' to 3691' 10-3/4" shoe 36~ Displace 9.8 brine with 9.6 LSND mud. 10:00 11:15 1.25 3,691 3,691 INTRM1 CEMEN" CIRC T Circulate bottom's up. Pumping 800 gpm w/ 1720 psi. Rotate 65 rpm. Aquire slow pump rates. Observe well f/flow- static. 11:15 12:00 0.75 3,691 3,691 INTRM1 CEMEN" FIT T Rig up, then perform FIT to 15.2 ppg EMW. 3691' MD= 2395' TVD, 9.6 MW, 700 si a lied ressure. 12:00 16:30 4.50 3,691 3,724 INTRM1 DRILL KOST T Begin operations for sidetrack of CD2-73P61 wellbore. Drill 11'/hr f/ 5'. Then .1'/min or 6' /hr. Pump 800 to 675 gpm w/ 1720 psi to 1345 psi. Rotate 120 rpm w/ 9k ft Ibs of torque. GeoPilot deflected 100%, 135R. 16:30 19:45 3.25 3,724 3,724 INTRM1 DRILL KOST T Troucah f/ 3718' to 3724'., Pump 800 gpm w/ 1720 psi. Rotate 120 rpm w/ 9k ft Ibs of torque. GeoPilot deflected 100%, 135R. Note :Departure of old well CD2073PB1 3724'. 19:45 21:00 1.25 3,724 3,732 INTRM1 DRILL KOST T Time drill f/ 3724' to 3732' (6'/hr). Pumping 810 gpm w/ 1800 psi. Rotate 120 rpm w/ 9k ft Ibs of torque. GeoPilot deflected 100%, 135R. 21:00 00:00 3.00 3,732 3,745 INTRM1 DRILL KOST T Time drill f/ 3732' to 3745' (6'/hr) Actul drilling time 2.54 hrs. Pumping 810 gpm w/ 1800 psi. Rotate 120 rpm w/ 9k ft Ibs of torque. GeoPilot deflected 100%, 156R. 7/25/2009 Drill 9-7/8" intermediate hole from 3745' to 5675'. Note: De arture from on final wellbore CD2-73PB1 3724'. 00:00 12:00 12.00 3,745 4,261 INTRM1 DRILL DDRL T Directional drill 9-7/8" intermediate hole f/ 3745' to 4732'. Pump a high vis nut plug sweep at 4071' w/ 50 to 100% increase in cuttin s. ~~ Page 19 of ~~ Time Logs Date From To Dur S. Depth E. De th Phase Code Subcode T Comment _____ T 12:00 00:00 12.00 4,261 5,675 INTRMI DRILL DDRL T Directional drill 9-7/8" intermediate hole f/ 4732' to 5675'. Pump high vis nut plug sweeps at 4576', 4975', 5118' and 5403' w/ 50 to 100% increase in cuttings. Sweeps were pumped to help keep bit and geoPilot clean. Diluted mud w/ 275 bbls of new mud while drilling @ 5340'. Kee in lubricants at 1-1/2 to 2%. 7/26/2009 Drill 9-7/8" intermediate hole from 5675' to 8181'. Note: De arture from on final wellbore CD2-73PB1 3724'. 00:00 12:00 12.00 5,675 6,862 INTRM1 DRILL DDRL T Directional drill 9-7/8" intermediate hole f/ 5675' to 6862'. Parameters @ 6862' (3529' TVD): PU wt 163k, SO wt 127k, Rot wt 147k, torque on bottom 11.5k ft Ib, torque off bottom 7.5k ft lbs. Pumping 700 gpm w/ 2230 psi. Rot 120- 150 rpm. Pump high vis nut plug sweeps (15 ppb) at 6015', 6300', and 6545' w/ 50 increase in cuttings. Sweeps were pumped to help keep bit and geoPilot clean. Diluted mud w/ 275 bbls of new mud while drilling @ 6240' and 6850'. Keeping lubricants at 1-1/2 to 2%. 12:00 00:00 12.00 6,862 8,181 INTRM1 DRILL DDRL T Directional drill 9-7/8" intermediate hole f/ 6862' to 8181'. Parameters @ 8181' (3995' TVD): PU wt 170k, SO wt 137k, Rot wt 153k, torque on bottom 12k ft Ib, torque off bottom 8.5k ft lbs. Pumping 800 gpm w/ 3120 psi. Rot 160 rpm. Pump high vis nut plug sweeps (15 ppb) at 6940' w/ little increase in cuttings. Sweeps were pumped to help keep bit and geoPilot clean. Diluted mud w/ 275 bbls of new mud while drilling @ 7440' and 8100'. Keeping lubricants at 1-1 /2 to 2%. Note: Hole packed off while ~ ng (picking up) a backream connection after drilling down @ 6926'. Dropped down, established circulation, and reamed at slower rate. 7/27/2009 Drill 9-7/8" intermediate hole from 8181' to 12006'. Note: De arture from on final wellbore CD2-73P61 3724'. Paa~~e 2~3 s~f 35 ~~ Time Logs Date From To Dur S De th E. De th Phase Cade Subcode T Comment ~__ 00:00 12:00 12.00 8,181 9,890 INTRM1 DRILL DDRL T Directional drill 9-7/8" intermediate hole f/ 8181' to 9890'. Parameters @ 9890' (4596' TVD): PU wt 205k, SO wt 133k, Rot wt 155k, torque on bottom 16k ft Ib, torque off bottom 12k ft lbs. Pumping 800 gpm w/ 2970 psi. Rot 170 rpm. Pump high vis nut plug sweeps (5 ppb) at 8826', 9840' w/little to none increase in cuttings. Sweeps were pumped to help keep bit and geoPilot clean. Diluted mud w/ 275 bbls of new mud while drilling @ 8750' and 9840'. Kee in lubricants at 1-1/2 %. 12:00 00:00 12.00 9,890 12,006 INTRM1 DRILL DDRL T Directional drill 9-7/8" intermediate hole f/ 9890' to 12006'. Parameters @ 12006' (5354' TVD): PU wt 260k, SO wt 131 k, Rot wt 172k, torque on bottom 19.5k ft Ib, torque off bottom 16.5k ft lbs. Pumping 800 gpm w/ 3020 psi. Rot 170 rpm. Pump high vis nut plug sweeps (5 ppb) at 11299' w/ very little increase in cuttings. Sweeps were pumped to help keep bit and geoPilot clean. Diluted mud w/ 275 bbls of new mud while drilling @ 10885' and 11870'. Keeping lubricants at 1-1/4 to 1-1 /2 %. 7/28/2009 Drilled 9 7/8" hole w/ GP f/ 12,006' to 15,045' -Changed out wash pipe in TD 00:00 06:00 6.00 12,006 12,618 INTRM1 DRILL DDRL T Drilled 9 7/8" hole w/ GP f/ 12,006' to 12,618' MD 5575' TVD ADT.- 2.98 hrs. ECD - 10.54 ppg Footage - 612' WOB 15/20 k RPM 170 GPM 800 @ 3020 psi String wt. PU 235 SO 147 ROT 185 Torque on/off btm.-18,000/13,000 ft/Ibs 06:00 07:00 1.00 12,618 12,618 INTRM1 RIGMNT SVRG T Change out leaking wash pipe on top drive -test new wash pipe to 3800 psi -circulated with cement hose @ 4 b m / 430 si while makin re airs 07:00 12:00 5.00 12,618 13,297 INTRM1 DRILL DDRL T Drilled 9 7/8" hole w/ GP f/ 12,618' to 13,297' MD 5,816' TVD ADT.- 3.03 hrs. ECD - 10.68 ppg Footage - 679' WOB 12/18k RPM 170 GPM 800 @ 3210 psi String wt. PU 242 SO 148 ROT 180 Torque on/off btm.- 20,000/14,000 ft/Ibs f'ay~ 21 €~f 3 z Time Logs Date From To Dur S._peptf~ _ _ E D~th Phase Code Subcode T Comme_ nt ___ 12:00 00:00 12.00 13,297 15,045 INTRM1 DRILL DDRL T Drilled 9 7/8" hole w/ GP f/ 13,297' to 15,045' MD 6440' TVD ADT - 6.88 hrs ECD 10.89 ppg Footage - 1748' WOB 15/25 k RPM 170 GPM 800 @ 3480 psi String wt. PU 250 SO 166 Rot 198 Torque on/off btm.-18,000/12,500 ft/Ibs 7/29/2009 Drilled 9 7/8" hole w/ GP f/ 15,045' to 17,638' 00:00 12:00 12.00 15,045 16,568 INTRM1 DRILL DDRL T Drilled 9 7/8" hole w/ GP f/ 15,045' to 16,568' MD 6,986' TVD ADT - 6.69 hrs ECD 11.01 ppg Footage - 1523' WOB 15/25 k RPM 170 GPM 780 @ 3860 psi String wt. PU 280 SO 158 Rot 205 Torque on/off btm.- 22,000/16,000 ft/Ibs ECD spike @ 16,272' - 200/250 psi increase whle backreamin 12:00 00:00 12.00 16,568 17,638 INTRM1 DRILL DDRL T Drilled 9 7/8" hole w! GP f/ 16,568' to 17,638' MD 6986' TVD ADT- 7.61 hrs ECD 10.85 ppg Footage - 1070' WOB 25/30 k RPM 150 GPM 770 @ 3860 psi String wt PU 304 SO 157 Rot 217 Torque on/off btm.- 22,500/17,000 ft/Ibs ECD spike @ 16,930' Hard spots @ 17,038' - 17,332' - 17,585' 7/30/2009 Drilled 9 7/8:" hole f/ 17,638' to 17,720' TD -Circ 3 X btms up -wiper trip to 16,365' - RIH to 17,720' -Circ btms up -Wiper trip to 16,356' - RIH to 17,720 (spot ream f/17,214' to 17,260') Circ & bump mud wt to 10.5 ppg -Wiper trip to 16,458' w/ pump only -RIH to 17,720' -Circ btms up -POOH spotting WBS/CL pills to 17,010' 00:00 00:30 0.50 17,638 17,720 INTRMI DRILL DDRL T Drilled 9 7/8" hole w/ GP f/ 17,638' to 17 720' MD 7305 TVD ADT- 0.54 hrs ECD 10.77 ppg Footage - 82' WOB 25/30 k RPM 150 GPM 775 @ 3750 psi String wt PU 303 SO 155 Rot 219 Torque on/off btm.- 23,000/19,500 ft/Ibs 00:30 04:45 4.25 17,720 17,387 INTRM1 DRILL CIRC T CBU x 3 - 775 gpm / 3750 psi / 150 rpm -stood back one stand every 30 minutes from 17,720' to 17,387' - Flow check well, static -Mud Wt. in/out 10.0 04:45 06:45 2.00 17,387 16,365 INTRM1 DRILL WPRT T BROOH from 17,387' to 16,365' - 760 gpm / 3580 psi / 150 RPM - no roblems -Flow check well, static r~~ge 22 of 35 Time Logs _ - { Date From To Dur S__De~th E. De th Phase _. Code Subcode T Carnment ~__ 06:45 07:30 0.75 16,365 17,669 INTRM1 DRILL TRIP T RIH from 16,365' to 17,669' -SOW 160K -Observed tight spots @ 16,435' (150K SOW), 17,015' (150 - 145K SOW), 17,230' (135 - 140 SOW) wiped up 17,210', secong pass SOW 150K, 17,274' (135 - 140 SOW) wiped up 17,250', secong pass SOW 150K, 17,589' (SOW 150K 07:30 10:00 2.50 17,720 17,387 INTRM1 DRILL CIRC T Precautionary wash and ream from 17,699' to 17,720' -PUW 295K SOW 160K -Pumped 40 bbl high vis sweep -Circ and condition mud - 760 gpm / 3750 psi / 150 rpm -stood back one stand every 30 minutes to 17,387' -Flow check well, static - Mud Wt. in/out 10.2 10:00 12:00 2.00 17,387 16,365 INTRM1 DRILL WPRT T BROOH from 17,387' to 16,365' - 760 gpm / 3710 psi / 150 RPM - no roblems -Flow check well, static 12:00 14:00 2.00 16,365 17,669 INTRM1 DRILL TRIP T RIH from 16,365' to 17,669' -SOW 155/165K -Observed tight spots @ 16,972' & 16.990' (145K SOW), 17,037' to 17,104' (150 - 155K SOW), 17,190' (145K SOW), 17,218' (140K SOW), 17,221 (135K SOW) - POOH to 17,200' -Wash and ream from 17,200' to 17,294' - 700 gpm / 3440 psi / 140 rpm -back ream same interval - no problems while reaming hole -slid stand down without pumps - 165K SOW - Continued to RIH on elevators very short tight spots @ 17,550' (145K SOW), 17,580' (140K SOW), 17,660' 140K SO 14:00 16:45 2.75 17,720 17,387 INTRM1 DRILL CIRC T Precautionary wash and ream from 17,699' to 17,720' -PUW 309K SOW 163K -Circ and condition mud - 760 gpm / 3810 psi / 120 rpm - Stood back 4 stands to 17,387' - increased mud wt. to 10.5 ppg in and out. -Flow check well, static 16:45 19:00 2.25 17,387 16,458 INTRMI DRILL WPRT T POOH w/ pumps @ 500 gpm @ 1800 psi w/ no rotation f/ 17720' to 16,458' - PU wt. 275 - 295 -tight spot @ 17357' -Flow ck fluid level dro ed 6" below flow line 19:00 20:00 1.00 16,458 17,720 INTRM1 DRILL TRIP T RIH f/ 16,458' to 17,720' -Average SOW 160 k- 165 k- PU wt. @ 17,720' - 295 k 20:00 22:45 2.75 17,720 17,720 INTRM1 DRILL CIRC T Circ btms up @ 17,720' - 750 gpm @ 3850 psi w/120 rpms -Spot WBS/CR pills in drill string -flow ck well static ~ax~e 23 of ~~ • Time Logs Date From To Dur S De th E. De th Phase Code Subcode T Comment 22:45 _ 00:00 1.25 17,720 17,010 INTRM1 DRILL TRIP T _ _ POOH f/ 17,720' to 17,010' -spotting WBS/CL pills @ 3.5 bbls /min w/ No rotation -average PU wt. 275 to 305 k 7/31 /2009 POOH spotting WBS/CL pills f/ 17010' to 16548' - BROOH to 15,527' -POOH on TT f/ 15,527' to 11520' - Ream tight spot @ 11,520' to 11,394' (tight spot @ 11,480') -Cont. POOH on TT f/ 11.394' to 9,112' - BROOH f/ 9112' to 5200' -working through varrious tight spots -Made 3 attempts to POOH on TT unable to pull more than 3 stds without ullin 35k over 00:00 00:45 0.75 17,010 16,458 INTRM1 DRILL TRIP T POOH f/ 17,010' to 16,458' -spotting WBS/CL pills @ 3.5 bbls /min w/ No rotation -average PU wt. 290 k SOW 160K -Flow check well, static 00:45 02:30 1.75 16,458 15,527 INTRMI DRILL TRIP T Pump out from 16,458' to 15,527' - 450 gpm / 1470 psi / 120 rpm -PUW 230K SOW 155K -Flow check well, static 02:30 06:15 3.75 15,527 11,520 INTRM1 DRILL TRIP. T POOH on elevators from 15,527' to 11,520' -PUW 220 SOW 150K 06:15 07:00 0.75 11,520 11,394 INTRMI DRILL TRIP T Backream from from 11,520' to 11,394' - 500 gpm / 1750 psi / 90 r m - Ti ht s of at 11,480' 07:00 10:00 3.00 11,394 9,112 INTRM1 DRILL TRIP T POOH on elevators from 11,394'to 9112' -PUW 195K SOW 135K wiped through tight spots @ 10,700', 10,100', 9,211 & 9,136' 10:00 11:45 1.75 9,112 8,827 INTRM1 DRILL TRIP T Backream from 9,112' to 8,827' - 600 gpm / 2000 psi / 130 rpm -tight spots @ 9,079', 9,008', 8,883', 8,875', 8,854', 8,842' -flow check well, static 11:45 12:00 0.25 8,827 8,711 INTRM1 DRILL TRIP T POOH on elevators from 8,827', unable to work through tight spot @ 8,711' w/ 50K over 12:00 14:00 2.00 8,731 8,542 INTRM1 DRILL TRIP T Backream tight hole from 8,731' to 8,542' - 500 gpm / 1580 psi / 100 rpm - obseved 200 psi pressure loss - determined mud aired up -condition mud with defoamer and screen clean while reamin 14:00 15:15 1.25 8,542 8,351 INTRM1 DRILL TRIP T Continue to Backream from 8,542' to 8,351' - 500 gpm / 1580 psi / 100 rpm - no tight spots observed on last stand 15:15 15:30 0.25 8,351 8,351 INTRM1 DRILL TRIP T Attempt to POOH on elevators from 8351', unable to work through tight s of 8,331' w/ 50K over 15:30 19:45 4.25 8,351 6,450 INTRMI DRILL TRIP T Cont. to BROOH f/ 8351' to 6450' @ 500 gpm @ 1450 psi w! 90 rpm's - 10 K torque -worked through spots @ 7830', 7700', 7450' 7365' , 7163' , 7193' ,& 7182' 19:45 21:00 1.25 6,450 6,450 INTRM1 DRILL CIRC T Circ btms up @ 400 gpm @ 1000 psi w/ 90 rpm's 8 k torque to even out mud wt. 10.5 ppg in ~ out -Flow ck. well static Page 2~ of 3 • Time Logs ______ I Date From To Dur S. De th E. De th Phase Code Subcode T Comment 21:00 21:30 0.50 6,450 6,165 INTRM1 DRILL TRIP T POOH on TT f/ 6450' to 6140' - pulling tioght @ 6140' (35 k over) RIH to 6165' 21:30 00:00 2.50 6,165 5,200 INTRM1 DRILL TRIP T Cont. BROOH f/ 6165' to 5200' - 500 gpm @ 1360 psi w/ 90 rpm's - 8 k for ue 8/01 /2009 BROOH f/ 5200' to 3786' -Circ & pump nut plug sweep to help clean 10 3/4' csg -flow ck static -Cut & slip drill line -adjust TD dollies to center TD over hole - repair wt. indicator -Circ & spot low YP mud in casing / DP annulus -POOH on TT - LD ghost reamers, jars & NM flex DC's -Down load MWD - LD MWD & GeoPilot -Chan a to i e rams for casin & test - RU to run casin -Ran 7 5/8" casin to 2985' 70 'ts. of 414 to run 00:00 02:15 2.25 5,200 3,786 INTRM1 DRILL TRIP T BROOH f/ 5,200' to 3,786' - 500 gpm @ 1360 psi w/ 90 rpm's - 8.5 k for ue -Flow check, static 02:15 03:30 1.25 3,786 3,596 INTRM1 DRILL CIRC T Circulate and condition F/ 3,786' T/ 3,596', pump nut plug sweep - 500 gpm @ 1360 psi w/ 90 rpms and 9k for ue -flow check static 03:30 05:30 2.00 3,596 3,596 INTRM1 DRILL SLPC T Cut and slip 60' drilling line, service top drive, adjust top drive dollies and center over hole. Bleed air from deadline sensor 05:30 06:00 0.50 3,596 3,596 INTRM1 DRILL CIRC T Circulate and condition mud - 9.5 bpm @ 770 psi. Spot lower YP mud in annulus, flow check static 06:00 10:15 4.25 3,596 732 INTRM1 DRILL TRIP T POOH on TT F/ 3,596' T/ 732' - PUW 100k, SOW 95k -Flow check @ HWDP static 10:15 13:15 3.00 732 79 INTRM1 DRILL TRIP T Cont. POOH on TT F/ 732' T/ 79'. Stand back HWDP, lay down jars, flex collars -plug into MWD & down load data -Pull up & break bit & service GeoPilot(while plugged in) - LDMWD & GP -clean up & clear tools f/ ri floor 13:15 13:30 0.25 0 0 INTRM1 DRILL SFTY T PJSM on changing rams 13:30 16:15 2.75 0 0 INTRM1 WELCTL OTHR T Change top pipe rams f/ 3 1/2" x 6' VRB to - u weear pus ung set test plug -Test 7 5/8" pipe rams to 250 & 3500 psi -Pull test plug & set thin wall wear bushing (changed TD 'unk sub while Chan in rams 16:15 19:00 2.75 0 0 INTRM1 CASING RURD T RU to run 7 5/8" casing - MU fill up tool -Observed btm connection on fill up tool not made up right -Changed out fill u tool 19:00 19:15 0.25 0 0 INTRM1 CASING SFTY T Held PJSM with rig crew & service hands for runnin 7 518" casin F~~e 2~ €sf 3~ Time Logs _ e T Comment _ ate From To D ur S De th E. De th Phase Code Subcod D __ 19:15 00:00 _ 4.75 0 2,985 INTRM1 CASING _ RNCS T Ran 7 5/8" 29.7 # L-80 BTCM casin as follows: Float shoe (Ray Oil Tools silver bullet) 2 Jts casing -float collar (Halliburton Super Seal II w/ by-pass baffle on top) 1 jt casing -Baffle collar (Halliburton) - 1 jt. casing (all connections made up w/ BakerLoc - filled pipe -circ & check floats) - 66 jts casing to 2985' (70 jts total in hole 8/02/2009 Ran 7 5/8" 29.7# L-80 BTCM casing f/ 2985' to 15,665' (367 jts total in hole of 414 to run) Circulated & condition mud 3,688' - 7,063' -10,263' & 13,454' - PUwt 15,665' 400 - SO wt 165 00:00 01:00 1.00 2,985 3,688 INTRM1 CASING RNCS T Cont. to run 7 5/8" 29.7 # L-80 BTCM casing from 2,985' to 3,688' (86 jts total in hole) -PUW 149K SOW 125K 01:00 01:30 0.50 3,688. 3,688 INTRM1 CASING CIRC T Circulate and condition mud -Stage pumps up to 7 bpm -FCP= 540 psi PUW 144K SOW 135K 01:30 05:45 4.25 3,688 7,063 INTRM1 CASING RNCS T Ran 7 5/8" 29.7 # L-80 BTCM casing from 3,688' to 7,063' (165 jts total in hole -PUW 198K SOW 135K 05:45 06:45 1.00 7,063 7,063 INTRM1 CASING CIRC T Establish circulation @ 3.5 bpm / 290 psi -Circulate and condition mud -stage pumps up to 8 bpm -FCP= 740 si PUW 190K SOW 135K 06:45 11:45 5.00 7,063 10,262 INTRM1 CASING RNCS T Ran 7 5/8" 29.7 # L-80 BTCM casing from 7,063' to 10,262' (240 jts total in hole -PUW 276K SOW 148K 11:45 13:00 1.25 10,262 10,262 INTRMI CASING CIRC T Establish circulation @ 3.5 bpm / 370 psi -Circulate and condition mud -stage pumps up to 7 bpm -FCP= 720 si PUW 250K SOW 142K 13:00 17:30 4.50 10,262 13,454 INTRMI CASING RNCS T Ran 7 5/8" 29.7 # L-80 BTCM casing from 10,262' to 13,454' (315 jts total in hole -PUW 350K SOW 153K 17:30 19:30 2.00 13,454 13,454 INTRM1 CASING CIRC T Establish circ @ 3/5 bbls/min @ 520 psi -FCP @ 7 BBLS/MIN @ 700 PSI - PU wt. 300 SOwt. 150 19:30 00:00 4.50 13,454 15,665 INTRM1 CASING RNCS T Ran 7 5/8" 29.7 # L-80 BTCM csg f/ 13,454' to 15,665' (367 jts total in hole of 414 to run) PU wt. 400 SO wt. 165 8/03/2009 Ran 7 5/8" csg to 16,480' -Circ -Ran 7 5/8" csg to 16,908' -Wash down csg f! 16,809' to 17,704' -Landing casing on Hued hanger w/shoe @ 17,705' - RD csg equip - Ru cmt head & lines -Circ & cond. for cmt job - Cmted 7 5/8" -stage 1 f/ 17,705' to 16,148' w/ 93 bbls - 15.8 ppg class G -Open stage collar & pumped stage 2 f/ 8933' to 7884' w/ 58 bbls - 15.8 ppg class G - RD f/cmt job -set & test pack-off -change upper pipe rams - LD 5" DP 00:00 01:00 1.00 15,665 16,480 INTRM1 CASING RNCS T Ran 7 5/8" 29.7 # L-80 BTCM csg f/ 15,665' to 16,480' (386 jts total in hole of 414 r U wt. 430 SO wt. 165 r~ac~€~ 2~a tit 3~ Time togs Date From To Dur S De th E. De th Phase Code Subcode T Comment ___ _ 01:00 04:00 3.00 16,480 16,480 INTRM1 CASING CIRC T Establish circ - 3.5 bpm / 540 psi - stage pumps up to 6 bpm -Circulate and condition mud -FCP 780 psi - PU wt. 375 SOwt. 160 Mud wt. in 10.7 -Mud wt. out 10.8 04:00 05:00 1.00 16,480 16,908 INTRM1 CASING RNCS T Ran 7 5/8`,' 29.7 # L-80 BTCM csg f/ 16,480' to 16,908' (396 jts total in hole PU wt. 460 SO wt. 160 05:00 08:15 3.25 16,908 17,704 INTRM1 CASING RNCS P Run casing -Circulate down from 16,908' to 17,667' - 2.0 bpm - MU FMC fluted hanger and LJ -land han er in wellhead - FS 17 704' FC 17,616', Baffle insert collar 17,576' (414 jts. Total) SOW 130 - 160 KLast break over PUW @ 17,667' 485K - 08:15 08:45 0.50 17,704 17,704 INTRMI CEMEN" RURD P RD casing running tools - LD fill up tool -blow down Top drive -install cement head and lines 08:45 12:15 3.50 17,704 17,704 INTRM1 CEMEN" CIRC P Establish circulation @ 2.5 bpm / 570 psi -stage pumps up to 7 bpm - circulate and condition mud -FCP = 760 psi -Mud Wt. in 10.5 ppg Mud wt. out 10.65 ppg - No pipe movement - PJSM on cementing o erations 12:15 15:30 3.25 17,704 17,704 INTRM1 CEMEN" CMNT P Cemented 7 5/8" casing as follows: Pumped 5 bbls CW 100 -Pressure test lines to 4100 psi -Pumped 55 additional bbls CW-100 -Mix & pumped 75 bbls - 13.0 ppg MudPush - Dropped btm plug -pumped last 5 bbls of MudPush -Loaded top plug in cement head. Mixed & pumped 93 bbls (450 sxs) 15.8 pg, 1.16 yield tail slurry (Class G w/ additives) - Dropped top plug w/ 20 bbls fresh water f/ Dowell -Switched to rig pumps & displaced cmt w/ 794 bbls of 10.5 ppg mud -Displaced @ 7.7 bbls/min - 430 psi to 130 psi for first 780 bbls -slowed pumps to 4 bbls/min for last 14 bbls of displacement. Final displacement ressure 520 psi. Bumped plug to 1000 si -Had full returns throu hout job - CIP @ 1512 hrs- Calc TOC @ 16,138'. Floats held -Load closing plug for stage 2nd stage. Did not reciprocate casin while cementin due to excessive break over PUW 485K 15:30 15:45 0.25 17,704 8,933 INTRM1 CEMEN" CIRC P Pressured u on cs , Halliburton ES sta a II r - (top @ 8,933') -Circulated hole through stage collar @ 7 bpm / 350 si Pa~~ ~7 of 3~ • Time Lo.~ _ __ Date From To Dur S. De th E. De th Phase Code Subcode T Comment 15:45 17:45 2.00 8,933 8,933 INTRM1 CEMEN" CMNT P Line u to Dowell - 2nd sta a cmt'ob as follows: Pumped 40 bbls CW-100 -Mixed & pumped 50 bbls of MudPush at 13.0 ppg. Mixed & um ed 58 bbls 280 sxs 15.8 tail slurry (Class G w/ additives). Dropped closing plug w/ 20 bbls water f/Dowell -switched to rig pumps and displaced cmt w/ 392 bbls of 10.5 ppg mud. Displaced @ 8 bpm, ICP 320 psi, max press. 410 psi, slowed pumps. to 4 bpm for last 15 bbls of displacement FCP=250 psi. Bumped plug to 2,500 to close sta a tool held ressure for 5 minutes - CIP @ 1725 hrs. Calc TOC 7884'. Had full returns throu hout ~ob 17:45 18:30 0.75 0 0 INTRM1 CEMEN" RURD P RD cmt lines & head - LD landing jt - lon bails & casin elevators 18:30 19:30 1.00 0 0 INTRM1 DRILL OTHR P Pull thin wall wear bushing -Set 7 5/8" pack-off & test to 5000 psi for 10 mins. 19:30 20:30 1.00 0 0 INTRM1 WELCTL EORP P PJSM on changing pipe rams - Chan ed top pipe rams f/ 7 5/8" to 3 1/2" x 6" VBR Note -Didn't test rams -Will test on bi-week) BOP test - 8/4/09 20:30 00:00 3.50 0 0 INTRM1 DRILL PULD P PJSM on laying down 5" DP - LD 5" D f/derrick via mouse hole 8/04/2009 LD 5" DP - RU & Test BOPE - Cut ~ Slip drill line - MU BHA #5 (clean out assembly). Note: Flushed OA w/ 300 bbls H2O and freeze rotected w/ 68 bbls diesel after in~ectivi test. 00:00 05:00 5.00 0 0 INTRM1 DRILL PULD P Cont. LD 5" DP f/ derrick via mouse hole 05:00 05:30 0.50 0 0 INTRM1 DRILL OTHR P Service rig 05:30 13:15 7.75 0 0 INTRM1 DRILL PULD P Cont. LD 5" Dp f/derrick via mouse hole 13:15 13:45 0.50 0 0 INTRM1 DRILL RURD P LD 5" elevators -Change out iron rough neck heads for 4" DP - PU test 't. 13:45 19:30 5.75 0 0 INTRM1 WELCTt BOPE P Set test plug - RU to test BOPE - Tested B P - ydril to 250 & 2500 psi -pipe rams, choke manifold valves, kill & choke line valves, TD IBOP's, floor safety & dart valves to 250 & 3500 psi - w/ 4" test jt - Pertormed accumulator recovery test - Pulled test jt -Tested blind rams to 250 & 3500 psi. -Installed 4 1/2" test jt -Tested Hydril to 250 & 2500 psi - Tested upper & lower pipe rams to 250 & 3500 psi -Blow down kill & chkoe lines & choke manifold - Pulled test plug - wittnessing of test waived b Jeff Jones AOGCC 1 ~...._. ~. ~'a~~ 2~ of 35 • Time Logs ___ ~ ____ ___ Date From To Dur S. De th E. De th Phase Code Subcode T Comment 19:30 20:00 0.50 0 0 INTRMI DRILL OTHR P Set wear bushing 20:00 20:15 0.25 0 0 INTRMI DRILL SFTY P PJSM on cut & slip drill line 20:15 21:30 1.25 0 0 INTRM1 DRILL SLPC P Cut & slip drill line 21:30 22:00 0.50 0 0 INTRM1 DRILL PULD P Pick up & std back 6 stds 4" DP 22:00 00:00 2.00 0 314 INTRM1 DRILL PULD P MU BHA # 5 -Clean out assembl - Milltooth bit -bit sub -Stab - Batsonic - (3) NM flex DC's - XO - (3) HWDP -Combo jars/drilling bumper sub - 2 HWDP 8/05/2009 RIH w/ BHA# 5 -picking up 4" DP f/ shed - to 8802' -Test csg to 1000 psi -Wash down to 8933' -drill out stage collar - Wash down to 9375' -POOH to 8802' (std pipe in derrick) RIH f/ 8802' PU 4" DP f/shed to 17,205' -Wash down w/ DP f/derrick to 17566' -Circ & test csg to 3500 psi -Spot mud w/ tube beads -Drill cmt & wi er lu to 17,576' - 00:00 06:30 6.50 314 8,802 INTRM1 DRILL TRIP P RIH w/ BHA # 5 picking up 4" DP f/ pipe shed to $802' - PW wt 160 SO wt 112 filled i e eve 20 stds 06:30 06:45 0.25 8,802 8,802 INTRM1 DRILL PRTS P RU & test casing to 1000 psi for 5 mins. 06:45 09:30 2.75 8,802 8,933 INTRM1 DRILL REAM P Wash & ream f/ 8802' to 8933' (w/ DP f/ derrick) Drill out stage collar @ 8933' - 300 gpm @ 1620 psi - 100 r m-18kWOB-9ktor ue 09:30 10:15 0.75 8,933 9,357 INTRMI DRILL REAM P Cont. wash & ream f/ 8933' to 9357' - 300 gpm @ 1540 psi - 100 rpm - 11 k toru e 10:15 10:45 0.50 9,357 8,802 INTRM1 DRILL TRIP P POOH f/ 9357' to 8802' - PU wt 160 SO wt. 107 -Flow ck -static 10:45 11:15 0.50 8,802 8,802 INTRM1 DRILL PRTS P PJSM - RU & test casin to 3500 si for 10 mins.- RD 11:15 18:45 7.50 8,802 17,205 INTRM1 DRILL TRIP P Cont. RIH w/ BHA #5 - f/ 8802' to 17,205' -picking up 4" DP f/ shed - PU wt 273 SO wt. 120 (filled pipe eve 20 stds 18:45 20:00 1.25 17,205 17,566 INTRM1 DRILL REAM P Wash & ream f/ 17,205' to 17,566' - 300gpm @ 2780 psi -RPM 60-80 - 19 k for ue 20:00 21:00 1.00 17,566 17,566 INTRM1 DRILL CIRC P Circ for casing test - 300 gpm @ 2780 si - 80 RPM - 19 k for ue 21:00 22:30 1.50 17,566 17,566 INTRM1 DRILL PRTS P RU & Test 7 5/8" casing to 3500 psi for 30 mins. ood test bleed off pressure & RD Obtained torque data - PU 300 SO 110 Rot 168 20 k for ue 22:30 23:00 0.50 17,566 17,566 INTRM1 DRILL CIRC P Spot mud w/ 6 #/bbl Lubra beads to bit - 300 m 2780 si 23:00 00:00 1.00 17,566 17,576 INTRM1 CEMEN' DRLG P Clean out cmt & drilled top wiper ~lu to 17 576' 300 gpm @ 2850 psi - 50 RPM - 21 kfor ue 8/06/2009 Circ lube beads into mud system -Clean out shoe track- Clean out rat hole to 17,707' -Circ hole clean for MADD pass -MADD pass w/ BAT Sonic to 16,000; -RIH -Drill 20' new hole to 17,740' -Circ & condition mud for FIT -Perform FIT to 13.0 EMW -POOH w/ clean out assmebl to 10,285' e r ~t~~ 29 cst 3S .~ i i Time Logs . _ _~ _____ _ Date From To Dur _ S__De~th E. De th Phase Code Subcode T Comment ___ 00:00 00:30 0.50 17,576 17,576 INTRM1 CEMEN" CIRC P Wash & ream f/ top baffle collar @ 17,566' to 17,576' while circulating tube beads to surface - 300 gpm @ 2570 psi w/ 90 rpm @ 21 k torque - PU wt 309 SO wt. 110 Rot wt. 170 w/ 20 k torque * Note -top baffle collar @ 17,566' - drill i e measurement 00:30 03:00 2.50 17,576 17,707 INTRM1 CEMEN" DRLG P Drilled shoe track - mt f/ 15,576' to 17,607' -Drilled btm plug & FC to 17,608' -drilled cmt f/ 17,608' to 17,693' -drilled FS @ 17,693' to 17,694' -Cleaned out rat hole to 17, 707' * Note -All depths are actual drill i e measurements 03:00 04:00 1.00 17,707 17,707 INTRM1 DRILL CIRC P Circ hole clean for MAD pass - 300 gpm @ 2700 psi w/ 90 rpm's @ 19.5 k torque Flow ck -well static 04:00 11:00 7.00 17,707 16,000 INTRM1 EVALWE QEVL P MADD ass with BAT Sonic f/ 17,707' to 16,000' @ 400'/hr. - Pumped @ 2.5 bbls/min - No rotation - PU wt. 290 SO wt. 112 -Flow ck. - well static 11:00 12:00 1.00 16,000 17,720 INTRM1 DRILL TRIP P RIH f/ 16,000' to 17,682'. Wash down to 17,720'- PU wt. 315 SO w. 100 12:00 12:30 0.50 17,720 17,740 INTRM1 DRILL DRLG P Drilled 20' new hole f/ 17,720' to 17,740' MD 7307 TVD ADT - .52 hrs. WOB 18/25 k RPM 70 GPM 300 2850 si 12:30 16:30 4.00 17,740 17,740 INTRM1 DRILL CIRC T Circ & cond. extremely cement contaminated mud for FIT- 280 gpm @ 2850 psi w/ 90 rpm's @ 20 k for ue 16:30 17:30 1.00 17,740 17,740 INTRM1 DRILL FIT P RU & perform FIT to 13.0 ppg EMW 7302' TVD w/ 10.0 ppg w/ 1150 psi - RD -Blow down kill & choke lines 17:30 18:30 1.00 17,740 17,205 PROD1 DRILL TRIP P POOH w/ clean out assembly on TT f! 17,682' to 17,205' - PU wt. 340 SO wt. 110 18:30 19:00 0.50 17,205 17,205 PROD1 DRILL CIRC P Flow ck.-well static -Pump dry job - Blow down TD 19:00 00:00 5.00 17,205 10,285 PROD1 DRILL TRIP P Cont. POOH w/ CO assembly f/ 17,205' to 10,285' 8/07/2009 POOH on TT f/ 10285' to 314' -Flow ck static - LD BHA # 5 - MU BHA #6 -Geo-Pilot assembly w/Geo TAP - Up load MWD -RIH to 403' & pulse test - RIH to 17,672' (picked up 177 jts 4" DP f/shed) -Cut & slip 60' drill line -Wash down to 17,740' -Circ btms u 250 m 2750 si 00:00 02:45 2.75 10,285 314 PROD1 DRILL TRIP P Cont. POOH on TT f/ 10,285' to 314' - Flow ck HWDP -well static 02:45 03:00 0.25 314 314 PROD1 DRILL SFTY P PJSM w/ crew on laying donw BHA P~cga; 3i} of 35 Time Logs _ Subcode T Comment Date From To Dur S De th E. De th Phase Code 03:00 04:00 1.00 314 0 PROD1 _ DRILL PULD P Handle BHA - LD 2 jts HWDP & combo jars/bumper sub -Std back 1 std HWDP & NM flex DC's -Pull up & break bit - LD Bat Sonic -Stab & bit sub Clean u ri floor 04:00 04:15 0.25 0 0 PROD1 DRILL SFTY P PJSM w/ crew, MWD, & DD on ickin u BHA 04:15 09:45 5.50 0 403 PROD1 DRILL PULD P MU BHA #6 -bit GeoPilot 5200 - GPflex -Smart stab - SP4/EWR/DRG -Smart stab - DM HOC -Geo-TAP - TM HOC - IB stab - NM float sub -Plug in & unload MWD - RIH w/flex DC's - PU jars - 1 jt HWDP -Bumper Sub - 1 jt HWDP f/ shed -RIH w/ 1 std HWDP f/ derrick to 403' -Pulse test tools - 275 gpm @ 1100 psi -Pull up to 77' & obtain Geo-TAP offset measurement - RI H f/ 77' to 403' 09:45 13:45 4.00 403 6,027 PROD1 DRILL TRIP P RIH w/ BHA #6 f/403' to 6027' - cikin u 177 ~ts 4" DP f/ i e shed 13:45 19:45 6.00 6,027 17,672 PROD1 DRILL TRIP P Cont. RIH w/ BHA # 6 f/ 6027' to 17,672' w/ 4" DP f/derrick (filling DP every 20 stds) -String took wt @ 12,942' - PU to 12,932' -Ran back throu h s of 12,942' -OK 19:45 20:00 0.25 17,672 17,672 PROD1 DRILL SFTY P PJSM on slip & cut drill line 20:00 21:15 1.25 17,672 17,672 PROD1 DRILL SLPC P Cut & slip drill line 60' -service TD Flow ck -well static -fluid level down 8.. 21:15 00:00 2.75 17,672 17,740 PROD1 DRILL CIRC P Break circ -wash down f/ 17,672' to 17,740' -Circ btms up -Stage pump up to 250 gpm @ 2750 psi / 30 rpm's w/21 k torque - PUW 280 Rot wt. 165 8/08/2009 Change over to 9.8 ppg FroPro -Monitor well (sllight flow) Obtain clean hole ECD data -Attempt to drill ahead - high torque -Circ 1/2 tote Low Torque & added nut plug -wash to 17,740' -Drilled 6 3/4" hole to 18,723' - Took Geo TAP data 17,824 - 17,939 - 18,166 00:00 00:15 0.25 17,740 17,740 PROD1 DRILL OTHR P Flow ck- well static -PJSM on dis lacin well to FlowPro 00:15 02:30 2.25 17,740 17,672 PROD1 DRILL CIRC P Displace well to 9.8 ppg FlowPro - 250 gpm @ 2280 psi w/ 50 rpm's - Pull back to 17,672' 02:30 03:45 1.25 17,672 17,672 PROD1 DRILL OTHR P Flow ck -Observed slight flow - Clean surface equipment in pit room -Obtain clean hole ECD data 03:45 05:00 1.25 17,672 17,672 PROD1 DRILL CIRC T Attempt to wash down f/ 17,672' to 17,740' - 300 gpm @ 3040 psi w/ 50 rpms' @ 23.5 ktorque -Drill string for uin up @ 23.5 k -Circ & add 1/2 tote of Low Torque -Begin adding med. nut lu b~~ge ~1 a~f 35 Time Logs _____ Date From 7o Dur S. De th E. De th Phase Code Subcode T Comment _ 05:00 12:00 7.00 17,740 18,054 PROD1 DRILL DDRL P Washed down to 17,740' Drilled 6 3/4" horz.section f/ 17,740' to 18,054' MD 7331' ND ADT - 5.06 hrs ECD- 10.96 ppg Footage - 314' WOB 8/12 k RPM 100 GPM 300 @ 3050 String wt PU 292 SO 130 Rot 190 Torque on/off btm.- 22,000/21,500 ft/Ibs 17,959' 12:00 00:00 12.00 18,054 18,723 PROD1 DRILL DDRL P Drilled 6 3/4" horz. section f/ 18,054' to 18,723' MD 7338' ND ADT- 723 hrs. ECD- 11.18 ppg Footage- 669' WOB 8/12 k RPM 120 GPM 300 @ 3160 psi String wt. PU 260 SO 145 Rot 190 Torque on/off btm.- 17,500!15,000 fUlbs @ 18,723' Obtained Geo Tap data @ probe depth - 17,824' @ 7.63 ppg - 17,939' 7.8 - 18,166' 7.67 8/09/2009 Drilled 6 3/4" horz section w/ GP f/ 18,723' to 20,346' -taking Geo TAP data every 500' 00:00 12:00 12.00 18,723 19,501 PROD1 DRILL DDRL P Drilled 6 3/4" horz. section w/ GP f/ 18,723' to 19,501' MD 7325' ND ADT- 8.27 hrs. ECD- 10.9 ppg Footage - 778' WOB 10/12 k RPM 120 GPM 300 @ 3320 psi String wt. PU 247 SO 140 Rot 191 Torque on/off btm.- 17,500/14,500 fUlbs Geo TAP @ 18,644' - 9.91 & 9.58 EMW (Low perm -supercharged) , 18,741' -7.56 EMW 19,217' - 7.52 EMW 12:00 00:00 12.00 19,501 20,346 PROD1 DRILL DDRL P Drilled 6 3/4" horz. section w/ GP f/ 19,501' to 20,346' MD 7327' ND ADT- 8.81 hrs ECD - 10.95 ppg Footage -845' WOB 10/12 k RPM 120 GPM 300 @ 3500 psi String wt. PU 250 SO 141 Rot 189 Torque on/off btm.- 18,000/14,000 ft/Ibs Geo TAP - 19,791' - 7.33 EMW, 20,267' - 7.25 EMW 8/10/2009 Drilled 6 3/4" horz. section w/ GP f/ 20,346' to 21,110' -Hole taking fluid -Spotted 20#/bbl LCM pill -Drilled 6 3/4" horz. section f/ 27 110' to 21 604' -Hole taking fluid -total losses 699 bbls -Average lose rate 49.9 ~ ~~~~~~ bbls/hr. Obtained Geo TAP data 20746' 7.15 EMW & 21,319' 7.12 EMW Paya: 32 of 3~ ~~ ~~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode' T Comment - 00:00 12:00 12.00 20,346 21,110 PROD1 DRILL DDRL P Drilled 6 3/4" horn. section w/ GP f/ 20,346' to 21,110' MD 7320' TVD ADT- 8.65 hrs ECD- 10.61 ppg Footage- 764' WOB 6/8 k RPM 120 GPM 230 @ 2380 psi String wt. PU 253 SO 135 Rot 185 Torque on/off btm.-19,500/16,500 ft/Ibs Geo TAP data @ 20,267' 7.25 EMW 20,747' 7.15 EMW Hole started taking fluid @ 21,020' @ - Lost 208 bbls for tour 12:00 13:45 1.75 21,110 21,110 PROD1 DRILL CIRC P Sot LCM ill - 20 #/bbl (5 # Nut plug fine - 5# CL Carb 30/50 - 10 #/bbl dynaRed mrd.) @ 228 gpm @ 2390 si w/ 60 r m 13:45 00:00 10.25 21,110 21,604 PROD1 DRILL DDRL P Drilled 6 3/4" horz. section w/ GP f/ 21,110' to 21,604' MD 7322' TVD ATD- 7.25 hrs ECD-10.85 ppg Footage- 494' WOB 8/12 k RPM 120 GPM 230 @ 2400 psi String wt. PU 250 SO 145 Rot 185 Torque on/off btm.- 19,000!16,000 ft/Ibs Hole takin fluid oing static on connections -lost 491 bbls FloPro last 12 hrs. Total losses past 24 hrs - 699 bbls Geo TAP data @ 21,319' - 7.12 EMW 8/11!2009 Drill 6-3/4" horz. section f/ 21,604' to 21,810'. Called early TD due to GeoPilot Failure. Circ clean, Pump out to shoe 17,672', CBU, Chan a over to 9.0 Brine, POOH 00:00 03:30 3.50 21,604 21,810 PROD1 DRILL DDRL P /GeoPilot f/ 21,604' to 21 810' MD / 7,329' TVD, ADT= 3.13 hrs, WOB 10/12K, 120 RPM, 230 GPM @ 2570 psi, Up 253K, Dn 135K, Rot 187K, Ave ECD's 10.88 ppg. Unable to control Geo-Pilot. Decision made to Stop drilling and TD the well earl . 03:30 09:30 6.00 21,810 21,810 PROD1 DRILL CIRC P Circ 3 times BTM's up at rate of 230 GPM @ 2450 psi, 120 RPM, Monitor well - Sli ht dro 09:30 17:00 7.50 21,810 17,672 PROD1 DRILL TRIP P Pump out of hole f/ 21,810' to 17,672' (Shoe) 200 GPM @ 1900 to 1750 si, 120 RPM, 14K T 17:00 19:15 2.25 17,672 17,672 PROD1 DRILL CIRC P Circ BTM's up at rate of 200 GPM @ 1810 psi, 120 RPM, Monitor well - Slightdrop, PJSM for Brine dis lacement Page 33 of 35 ~~ n Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 19:15 22:15 3.00 17,672 17,672 PROD1 DRILL CIRC P Displace well over to 9.0 ppg Brine, Monitor well -Fluid dropped 4" in 10 min. 22:15 00:00 1.75 17,672 16,240 PROD1 DRILL TRIP P POOH on elevators Note; Total mud loss to well for day 1125 bbls -Grand total 1824 bbls 8/12!2009 POOH, UD BHA, Wash Stack, Rig & run 4-1/2" Completion 00:00 08:30 8.50 16,240 403 PROD1 DRILL TRIP P Continue to POOH on elevators to BHA, Monitor well -Slight drop, Lay down HWDP & Jars 08:30 12:00 3.50 403 0 PROD1 DRILL PULD P Lay down Flex collars, Down load MWD, La down BHA & Clear floor 12:00 12:30 0.50 0 0 COMPZ DRILL OTHR P Rig & Pull wear bushing 12:30 13:45 1.25 0 0 COMPZ DRILL OTHR P Pick Stack washer & Flush Stack, Blow down to drive 13:45 14:15 0.50 0 0 COMPZ RPCOM OTHR P Pull Junk wear bushing, Set Com letion wear bushin 14:15 14:30 0.25 0 0 COMPZ RPCOM RURD P Rig to run 4-1/2" Completion 14:30 14:45 0.25 0 0 COMPZ RPCOM SFTY P PJSM for running 4-1 /2" Completion 14:45 00:00 9.25 0 9,082 COMPZ RPCOM RCST P Run 4-1/2" Completion as oer detail Note: Lost total of 68 bbls Brine for the da 8/13/2009 Ran 4-1/2" Completion & Landed same, Pump corrsion inhibitor brine & freeze protect well, Set Packer & test tubin & annluns to 3500 si- F/ 30 min, Set BPV & secure well 00:00 05:45 5.75 9,082 16,489 COMPZ RPCOM RCST P Continue running 4-1/2" Completion as er detail 05:45 06:15 0.50 16,489 16,489 COMPZ RPCOM RCST P Make up FMC retrieving tool & retrieve tubin wear bushin 06:15 07:00 0.75 16,489 16,520 COMPZ RPCOM HOSO P Make up Hanger & Land tubing @ 16,520', RILDS for Han er 07:00 07:45 0.75 16,520 16,520 COMPZ RPCOM MPSP P Lay down landing jt., Set 2-way check, Test Hanger seals to 5000 si-OK 07:45 08:15 0.50 COMPZ RPCOM OTHR P Lay down tubing equipment and clear ri floor 08:15 11:30 3.25 COMPZ RPCOM NUND P Nipple down BOP, Change out grab heads and saver sub to 4-1 /2" IF, Nipple up Tree & test to 5000 psi - OK 11:30 13:00 1.50 COMPZ RPCOM RURD P Rig up lubricator, Pull 2-way check, Rig up squeeze manifold for dis lacement Page 34 of 35 r~ Time Lo s Date From- To Dur S: De th E. De th Phase Cade Subcode' T Comment 13:00 21:45 8.75 COMPZ RPCOM PACK P PJSM, Test lines to 4000 psi, Displace well w/ 388 bbls 9.0 ppg corrosion inhibited Brine followed by 297 bbls diesel for freeze protect, Drop Packer ball and let fall Set Packer w/ 4000 si and test to in 30 min- OK, Bleed tubing to 2000 psi & pressure test annulus to 3500 osi f/ 30 min - OK Bleed off tubing and Shear DCK-2 valve, Bleed off all pressure (700 psi on tubing & 200 psi on annulus), Flush & Blow down all lines 21:45 00:00 2.25 COMPZ RPCOM OTHR P Set back pressure valve & secure well. Note; Totals volumes lost to well are 1824 bbls 9.5 ppg Mud and 68 bbls 9.0 Brine 8/14/2009 Lay down all 4" drill pipe, Service rig, Clear rig floor, Release rig to move 00:00 00:15 0.25 0 0 COMPZ MOVE SFTY P Hold PJSM on laying down DP from derrick 00:15 17:00 16.75 0 COMPZ MOVE PULD P. Install mousehole and Lay down 4" DP from derrick. 17:00 17:30 0.50 COMPZ RIGMNT SVRG P Service rig 17:30 23:00 5.50 COMPZ MOVE PULD P Continue to lay down 4"drill pipe from derrick 23:00 00:00 1.00 COMPZ MOVE RURD P Clear & Clean rig floor Note: Released rig at 24:00 hrs 8/14/09 Page 35 afi 35 i a ' ~ ~ ~ ~ ~ ¢ gp~py g 9g~~° ®®® SEAN PARNELL, GOVERNOR ALASSA OII. A1~TD ~zA-S 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQA'I`I011T COrII~iISSIOH ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Tim Schneider WNS Production Engineer ConocoPhillips Alaska, Inc 700 G Street Anchorage, AK 99501 Re: Colville River Unit, Alpine Oil Pool, Well CD2-73 (PTD 208-196) Sundry Number: 309-291 Dear Mr. Schneider: The Commission is returning the enclosed Application for Sundry Approval relating to the above-referenced well. The reason for returning this sundry is that well CD2-73 is already permitted for MWAG injection by AIO No. 18C. Additionally, CD2-73 was drilled and classified as a Service well as per the original PTD (208-196). Thus a 10-403 Sundry is not required to allow MWAG injection. Sincerely, Daniel T. Seamount, Jr. Chair DATED this? day of September, 2009 Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~~ l~U~ l 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Pertorate ^ Waiver ^ Oth Q- Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ MW injection Change approved program ^ Pull Tubing ^ Pertorate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill u mber: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 208-196 3. Address: Stratigraphic ^ Service 0 . 6. API Nu er: P. O. Box 100360, Anchorage, Alaska 99510 50-103- 590-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Numbe where ownership or landownership changes: Spacing Exception Requires? Y2S ^ NO ^~ CD2-73 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s) ADL 380075,387207, 387212, ASRCNPRA02 RKB 53' Colville River eld /Alpine Oil Pool ° 12. PRESENT WELL CONDITION SUMM Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (me ured): Junk (measured): 21810' 7328' Casing Length Size MD ND Burst Collapse CONDUCTOR 77~ 16" 114' 114' SURFACE 3627' 9.625" 365 2384' PRODUCTION 17668' 7.625" 177 7303' Perforation Depth MD (ft): Perforation Depth, (ft) Tubing Size: Tubing Grade: Tubing MD (ft): open hole completion 4.5" L-80 16520.75' Packers and SSSV Type: ac rs d SSSV MD (ft) Baker Premier pkr @ ~ 16 Camco landing nipople @ 2 5 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketc Exploratory ^ Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat A ust 24, 2009 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG Q GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true a correct to the best of my knowledge. Contact: Tim Schneider @ 265-6859 Printed Name TI SCh ider Title: WNS Production Engi neer Signature / Phone 265-6859 Date ~%- / - OcJ Commission Use Onl Sundry Number. Conditions of approval: Noti Commission so that a representative may witness Q~I- Plug Integrity ^ B Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent orm Required: ~~~~,~"~ ~ e ,~ °I !a Z~Q ~ APPROVED BY Appr ved by: O MISSIONER THE COMMISSION Date: Form 10-403 Revised 06/2006 v ~ ~ ! l,J ((V /'~ L Submit in Dupli~ G ~j®y' ~~~~~ 9 CD2-73 Formation Tops: To TVDSS MD C-30 C-20 2722 4754 K 3 mkr 3786 7884 Basal K-3 3983 8300 K 2 Mkr 4011 8371 Basal K-2 4097 8622 Albian 97 Albian 96 HRZ 6976 16682 Base HRZ 7048 16874 K 1 Mkr 7108 17039 Ku ruk Fm 7187 17281 LC U/M it uveach 7192 17299 AI ine D 7238 17588 Alpine C 7248 17678 UJU 7251 17708 B3 sand 7258 17781 AI ine A Sd 7265 17891 • Colville River Fuld • CD2-73 Cement Report: Daily report Summary: 8-3-09 _ ,.... _ _~.e_.___ _. __ - -,--__. ~)"stao°ish cirrulatian @ 2.5 bprr4 ; 57t3 ps, -stage pimps up to T bprn - circulate and roedit3nn rrrud - FGP = 7ti0 psi - h4"ud Wt. in 10.5 Ptsg ~llu~ wt. out t Q65 pP9 No pipe m~vernQnt - PJStyI crt cerngntin~ opsra ions Cemat?ted 7518" casing as follows: Pumped 5 obis CVI! 104 - Psstire test lines to 4100 psi Pumped~55 ?adtftional bbis GW-1 t}0 -Mix & pumped 75 bbis - 13.(1 ppg lVludPush - dropped btm ping - purr?ped lest 5 bbis of I MudPush -Loaded tap plug in cement head. Mixed & pumped 93 bbis (450 sxs) 15,8 ppg, 1..16 yield twit slurry { Class G wladditives} -Dropped top plug wl 20 bbis fresh water ft Dowell -Switched to r'rg pumps & displaced cmt wt 794 bbis of 10.5 ppg mud - Displaced ~ 7.7 bblslmin - 43dJ psi to 130 pal for first 780 %bls -slowed pumps to d bblstmin far last 1d bbis of displacement. Final displacement pressure 520 psi. Bumped plug to 1 ~Q psi -Had full re#urns throughout job - ClP ~ 1512 hrs-Cale TC7C ~ 16,138', Floats held -Load closing plug fior stags 2rrcl ,stage. Did not reciprocate rasing while cementing due to exc~sslve break over P't1W (d$5K} Pr$ssured up on cs~t, Hel'inurton ES stage roller operEed ~ 3400 psi -(top ~ 8,933') -Circulated holethrcrugh stage rcliar ~ 7 hpm 1350 psi Line up to Dowell - 2nd stage cri~tjab as follows: Pumped ~o bbis CUll-ltltt -Mixed & pumped 5D bbts of i,Audush at 13.U ppg. Mixed & pumped 58 bbEs (280 sxs) 15.8 ppg tai[ slurry t Glass G w1 additlus~}. Dropped closing plug w! 20 bbis water flDowell - switched to rig pumps and displaced cmt wI 392 bbis of 1 p.5 ppg mud, Displaced ~ 8 bprra, lGF' 320 psi, max press. 410 psi, slowed pumps to d bpm far last 15 bbts of displacement FCP=250 psi. Bumped plugs to 2,5110 to close stage tool, held pressure fors minutes - CIP ~x7 1725 hrs. Dalc 7CC 78$4'. Find full returns throughout jab WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Commission Attn.: Librarian 333 West 7`" Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD2-73 August 21, 2009 AK-MW-0006375986 CD2-73 2" x 5" MD TRIPLE COMBO Logs: 1 Color Log 50-103-20590-00 2" x 5" TVD TRIl'LE COMBO Logs: 1 Color Log 50-103-20590-00 Digital Log Images & LWDG-formatted LIS Data w/verification listing; 1 CD Rom 50-103-20590-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNIl~TG THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 Bryan.Burinda@halliburton.com Date: SEP d 1 2009 Signed ~,laska Oil ~ Cas Ccns• G®~~issiar~ Anc~ara~a ~- ~o~r ~~ ~ 1 ~~~~s ~- ~ ~ To: State of Alaska WELL LOG TRANSMITTAL Alaska Oil and Gas Conservation Commission Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD2-73 PB 1 CD2-73 PBl 2" x 5" MD TRIPLE COMBO Logs: 50-103-20590-70 2" x 5" TVD TRIPLE COMBO Logs: 50-103-20590-70 C~ August 21, 2009 AK-MW-0006375986 Digital Log Images & LWDG-formatted LIS Data w/verification listing; 50-103-20590-70 1 Color Log 1 Color Log 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax:907-273-3535 Bryan.Burinda@halliburton.com a ~~ Date: SEP 1 X000 ~,d~~ Oil has Ccr~se ~crn~*nission ~n~hnra~c Signed: a ~ ~ ConocoPhillips August 19, 2009 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application to inject MWAG into CD2-73 Dear Commissioner: T. Schneider WNS Production Engineer WNS P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6859 ConocoPhillips Alaska, Inc. completed drilling & completing the CD2-73 MWAG injector (Permit no. 208-196) on August 15, 2009. Reviewing the Sperry Sun BAT cement log dated August 7, 2009; the following assessment can be made: TOC ~ 16,120' Apparent Fair Bond 16,110' to 16,590' Apparent Good Bond 16,590' to 17,150' Apparent Fair Bond 17150' to 17260' Apparent Good Bond 17260' to 17490' Apparent Fair Bond 17490'to 17590' The K2(Qannik) was also isolated via a staged cement job across the interval (8933' - 7884' MD) Attached are the formation tops and cement report. A soft copy of the BAT Cement log was sent to you on Tuesday August 18 via e-mail for your review. Please don't hesitate to contact me if you need further information at 265-6859. Sincerely, Tim Schneider Production Engineer WNS Page 1 of 1 Schneider, Tim S. From: Schneider, Tim S. Sent: Tuesday, August 18, 2009 11:03 AM To: 'Maunder, Thomas E (DOA)' Subject: BAT CMT Evaluation: CD2-73: API 50-103-20590-00 Attachments: CD2-73.zip Tom, The Doyon 19 has completed the CD2-73 MWAG service injector in the Alpine "A" formation. The attached BAT file is for your review. We are currently completing the post rig slickline work. Formation tops are noted below: To TYDSS MD C-30 C-20 2722 4754 K ~ mkr 3786 7884 'Basal K 3 3983 8300 K Z Mkr 4019 8371 Basal K 2 4097 8622 Atbian 97 Alban 96 N RZ 6976 1888.2 K 1 Mkr 7108 1703.9 Ku aruk Fm 7187 17281 LCUMliluv each 7192 17299 Al ine 7238 17588 UJU 7251 177Q8 B3 sand 7258 17781 At in®A Sd 7265 17891 Tim 907-265-6859 Preliminary Results from BAT CMT Evaluation attached. TOC ~ 16,120' Apparent Fair Bond 16,110' to 16,590' Apparent Good Bond 16,590' to 17,150' Apparent Fair Bond 17150' to 17260' Apparent Good Bond 17260' to 17490' Apparent Fair Bond 17490'to 17590' 8/19/2009 CD2-73 Return from Rig Maintenance Maunder, Tomas E (RQA) From; Anderson, Nina M {Nina.Anderson. c(,,,Ticonocophillips.oom] Sen#; Tuesday, July 21, 2409 7:.17 AM To: Maunder, Thomas F (DMA) Subject: RF: CQ2-73 Return from Rig Maintenance ate ~- ,- ~~ Tom ~ i Rave nc~tit` -the rig and we plan to test the casingl~ nt plug for mina , Thanks_ Nina Ander~n Qrilling Engineer Allsine Qriiitng Team 'ce: ~947~=265 ~~ ll: ~9t'~7) 575 56 From. Maunder, Thomas E (LEA) jmaiito;tom.maunder@alaska,govJ Sent: Monday, July 24, 2449 7:18 PM To: Anderson, Nina M Cc: McKeever, Steve Subject: RE; Ct~2-73 Return from Rig Maintenance Page 1 of 2 Nina, to general the proposed steps are appropriate.. The one exception is that the casingfplug pressure- test prier to pulling the Dill string should be held for 34 minutes. A copy of this message should be available at the rig. Tom Maunder, PE AOGCC From: Anderson, Nina M jmaHto:Nina.Anderson@conocophillps.com] Sort. Mon 7/2fl/~Q09 4:51 PM To: Maunder, Thomas E (t~OA) C+c: McKeever, Steve Subject: CD2=73 Return from Rig Maintenance Tam Doyon 19 has moved back on to CQ2-73 and may restart operations as early week. CD2-73 was temporarily shutdown this past week for scheduled rig m~ known as CQ2-73PB1 was cemented at the shoe to P&A the well and isolate The floats were checked following the plug being bumped. The 7-5!$" casing was cut. and pulled to surface leaving a casing stub at was spotted from 4f~7' to 204' above the surface shoe at 3465' MQ. The wellbore currently contains a kill string to 2,439' MD and 9.8 peg kill weight procedure below and let us know if this is acceptable. Thanks. Wednesday the 22"d of this ~nance. The original wetlbore Kuparuk and A{pine reservoirs. 38?4' MC?. A cement plug Please review the planned 7121/~~49 CD2-73 Return from Rig Mainance ~ Page 2 of 2 1. Install two way check. 2. ND Tree. NU BOPE. Body test BOP and flange break. 3. Pull two way check. 4. Pressure tes# surface casing and cement plug to 3500 psi for 10 minutes. 5. Pull tubing hanger to floor and stand back kill string. 6. Set test plug and test BOPE to 3500 psi. Nina Anderson Drilling Engineer Alpine Drilling Team Office: (907)-265-6403 Cell: (907) 575-3256 7/21 /2009 ~ ~~ a ~ ~ ~ ~ ~ `~ °~ j SARAH PALIN, GOVERNOR ~ ~7 f ALASFiA OII. A1~TD GAS ~ 333 W. 7th AVENUE, SUITE 100 C01~TSERQA'1'IO1~T COM11IIS51OIQ ~d ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. C. Alvord ConoPhillips Alaska, Inc. Alpine Drilling Team Leader P.O. Box 100360 Anchorage, Alaska 99510 Re: Colville River Field, Alpine Oil Pool, CD2-73 Sundry Number: 309-237 Dear Mr. Alvord: 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, Cathy P. Foerster Commissioner DATED this ~~ day of July, 2009 Encl. ~o~ ' ~ 9 ~' ConocoPhillips Alaska, Inc. Post Office t3ox 100360 Anchorage, Alaska 99510-0360 Telephone 907.276-1215 July 10, 2009 ConocoPhillips ~E~G~~ Alaska Oil and Gas Conservation Commission JUL 1 Q 2009 333 West 7`h Avenue, Suite 100 ~iaska Oii & Gas Cans. Commission Anchorage, Alaska 99501 Rnchorage Re: Application for change to Approved Program- Plug back abandonment and re-drill operations (permit no. 208-196) Dear Sir or Madam: ConocoPhillips Alaska, Inc. horeby applies fora Permit for change to Approved Programs for CD2-73. Drilling operations on CD2-73 began on 1/5/2049 with Doyon 19 (permit no. 208-196). The surface section on CD2-73 was drilled and easing run and cemented, The ice road was ready, therefore, operations were suspended on CD2-73 anti Doyon 19 moved to CD3 on 1/10/2009. Doyon 19 moved back to CD2-y3 6/28/2009 and resumed operations. The intermediate section was drilled successfully to a TD of 17840' MD / 7309' TVD. On 7/8/09 the 7-5/8" casing stopped approximately 650 feet off bottom due to what appears to be unstable Kalubik shale. We had little movement up or down and very limited circulation. We re-established circulation to 4.5bpm. The decision was made to put cement to 500' annular apace above the casing shoe, Kuparuk, and Alpine. The cement operations occurred last night with full returns throughout the cement job. Fallowing the cement job, the casing was cut above the stage tool at 8220' MD. Throughout the day we have not been able to pull the 8220' of casing free. Therefore, the plan fon+vard is to pump cement out the stage tool to put cement above the Qannik. Then cut the casing again, 150' outside the surface shoe at 3800', Cement will then be pumped in and above the casing stub and up 200' inside the surface casing. A kill string of 5" drillpipe will be the left in the surface casing for the week of rig maintenance. The Alpine plant is having a planned shut down and the rig will not have highline power from July 19th -- 21 ¢`. Doyon 19 will have to move off the well row for rig maintenance and for facilities to hookup CD2~74 onto production. After rig maintenance, Doyon 19 will move back on CD2-73, kick off right outside the surface shoe and re-drill the intermediate section per the approved program in the permit to drill. The TD of the well will be within 500' of the plan in the permit to drill. Please find attached the information: 1. Form 10-403 APPLICATION FOR Sundry approval 2. A proposed plug back and drilling program 3. Current schematic 4. Plugback schematic. If you have any questions or require further information, please contact l-ix Galiunas at 265-6247 or Chip Alva~d at 265-6120. Sincerely, . ~~%~ l-ix Galiunas Drilling Engineer Attachments cc: CD4-318 Well File /Sharon Allsup prake ATp 1530 Chip Alvord ATO 1570 Nina Anderson ATO 1704 t_anston Chin Kuukpik Corporation ~~~~ ~ ~5 ~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL ~~~ 20 AAC 25.280 1. Type of Request: Abandon ^ ^ Operational shutdown ^ Perforate ^ Suspend Waiver ^ Other ^ Alter casing ^ f ^ Stimulate ^ Repair well L~ Plug Perforations Time Extension ^ Change approved program ^ r Pull Tubing ^ Perforate New Pool ^ Re-enter Suspenped Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to grill Number: ConocoPhillips Alaska, Inc. pevelopment ^ Exploratory ^ 208-196 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 103-20590-00 7. KB Elevation (ft): 9. Well Name and Number: 37' MSL, 51.9' RBK CD2-73 8. Property Designation: 10. Field/Pools(s): 380075, 387207, 387212, ASR CNPRA02 Coville River Field / A line Oil Pool PRESENT WELL CONDIT ION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth Mp (ft): Effective Depth TVp (ft): Plugs (measured) Junk (measured): 17840 7309 17162 7206 Casing Length Size MD TVD Burst Collapse Structural Conductor 77 16" 114 114 Surface 3620 9.625" 3657 2384 3520 2020 Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A Packers and SSSV Type: Packers and SSSV MD (ft): 12. Attachments: Description Summary of Prpposal Q 13. Well Class after proposed work: Detailed Operations Program 0 8pP Sketch [ ] rr----11 Exploratory ^ Development tPJ rr--11 Service L`Q 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 7/9/2009 Oil [] Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: pate` WAG [] GINJ ^ WINJ ^ WDSPL ^ Commission Representative: er 17. I hereby certify that the foregoing is true and corrpGt to the best of my knowledge. Contact L. Galiunas Printed Name C. AIVOrd by Alpine Drilling Team Leader Signature ~ ~~„ phone 265-6120 Date 7/10/2009 COMMISSION U5E ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ^ BpP Test ^ Mochanical Integrity Test ^ Location Clearance ^ ~p~ ~y~/.~q / Other: ired: ~ nt Form Re r S b ~® \ G~Q'n~ ~~~~~ 0.~ T~`~ST~'~"~C qu tiL u seque . c APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: '~- ~ ~~ Form 10-403 Revised 7/2005 O R I G I N A L ~ ~~~ ~~ zaag SUBMIT IN DUPLICATE • Cb2-73; Procedure 1. Pump cement per plan below to isolate the Qannik through the stage tool. Qannik Cement Jvb through stage tool: Cement from ports in a Stage tool at 8295' (K2 at 8371') to planned top of +/- 500' above the stage tool with Class G + additives @ 15.8 ppg. Assume 40% excess annular volume. Hold pressure to keep cement in place. Lead:(8295'-7795') X 0.2146 ft3/ft X 1,4 (40% excess) = 150.22 ft3 annular vol. Total Volume = 150,22 ft3 => 129 Sk @ 1.17 ft3/sk System:129 5x Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1 % S002 accelerator @ 15.8 PPG yielding 1.17ft3/sk 2. RU and RIH with E-line and radial cutting torch to cut casing. Cut the 7-5/8~ casing at 3800' (+/-150' outside of surface shoe: 3657' MD). 3. If the radial cutting torch will not make it to 3800', RIH with a pert guns to punch hole in the casing to allow for circulation to help the radial cutting torch reach 3800' MD. 4. POOH with ~-line tools and rig down E-line. 5. POOH with 7-5/8". Install thin wear bushing. Change top pipe rams to 3-1/2" to 6" variables. Test Rams to 3500 psi. 6. RIH with cement stringer on 5" DP to place cement from the casing stu~up to 3400' (including 50' or so laid inside casing stub). This will bring cement back into the surface casing about 200' up from the shoe. 7. POOH and Lp cement stinger. Pull thin wear bushing. RIH with 5" DP as kfll string to 2000' MD. Cross over and land hanger. ND the BOPEs, NU the tree and test. Pump diesel freeze protect. Set BPV. 9. LD drill pipe and move off well for rig maintenance. 10. After rig maintenance, move back onto CD2-73, side track, re-drill the intermediate section, and resume approved operations from the permit to drill. ~ r CD2-73 Injection Well Stuck 7-5/8" Casing Updated 07/10/09 ACTUAL. HES Stage Tool Set high +/- 8295' MD 8220' Cut made with E- line. Casing not free Actual 7-5/8" Casing Shoe Stuck +!- 654' high at 17,162' MD Top Kuparuk 17280' MD / ' i„ ; 7240' ND '' ' ~ _ _ ACTUAL ~ `\ _ .. - I Top Alpine C 17763 MD / 7305 TVq~ ~. I ~__. ~ ~ I Top Alpine R3v___T___ ~,_......._-.J 10-314" 45.5 ppf L-80 BTC-mod Surface Casing Actual ~ 365T MD J 2384' TVD cemented to surface Estimated TOC 16,600' MD +/• 680' above the Kuparuk ACTUAL 9-710" TD of the Well in the lower Alpine C sands 17,840' Mp / 7309' ND Top Alpine A Plugback Updated 07/10/09 16" Conductor to 114' 8220' Cut made with E- line, Casing not free 8371' MD / 4063' TVD 5" DP used as kill string down to 2000' MD 10-3/4" 45.5 ppf L-80 BTC-mod Surtace Casing Actual ~ 3657' MD ! 2384' TVD cemented to surface Stage Tool Set high +!- 8295' MD ACTUAL Estimated TOC 16,600' MD +l. 680' above the Kuparuk i Actual 7-518" Casing Shoe Stuck +!- 654' high at 17,162' MD ACTUAL, Top Kuparuk 17280' MD / 7240" TVD .~ ~~ I ~~ I ~~ I ACTUAL 9-718" TD of tha Well in the lower Alpine C sands 17,840' MD / 7309' ND ACTUAL, Top Alpine C 17763 MD 17305 TVD Top Alpine B3 Top Alpine A CD2-73 Stuck Casing Plan Fod Maunder, Thames E (QUA) From: Gaiiunas, Elizabeth C [Elizabeth.C.Galiunas~conocophillips.com] Sent: Friday, Juty 10, 2009 3:1Q PM To Maunder, Thomas E (D4A) Subject: RE: CR2-73 (208-196) Stuck Casing Plan Forward Page 1 of 2 Tom, the sundry is on its way over to you. The directions{ plan has not been completed, since sidetrack operations are about 10 days out. Once the directional is complete it will be sent over next week. Thanks, Liz Gaiiunas Alpine ©rilling Engineer ConecoPhiUlps Alaska Office: 907-265-6247 Cell: 907-9Q2.12t10 m: Maunder, Thomas E (DQA) [mailto:tom.maunder@alaska.gov] Se :Friday, 7uly 10, 2009 9:44 AM T,o: unas, Elizabeth C; McKeever, Steve Subject. :CD2-73 (208-296) Stuck Casing Plan Forward From: Maunder, Thom. E (pf3A) Sent; Friday, July 20, 2 6:30 AM To; 'Anderson, Nina M' Cc: Wheatall, Michael; Alvord, _ ,p Subject: RE: Cp2'73 (208-296 k Casing flan Fo d lFom: Anderson] Ni M [mailto:Nina.Ander sent: Thursday, y v9, 2009 ~:48 PM To; Maunder omas E (p0A) Cc: Whea ,Michael; Alvard, Chip Sub] .Cpl-73 Stuck Casing Plan Forward Tom -- d appear that your purl should a ively provide isolation. As cif the sands bul i~lataon should ievedr I will Eook fa d crf tuning do you a for tt-e activi~ ? As discussed this rooming, Doyon 19 is on CD2-73. 1Afiile running 7-5/8N intemtediate casing, the easing shoe slapped at approximately +~- 17,.162' ttAD. This depth is 654' from the planned casing pt~int of 1'7,816' MD. ll is 7/10/2009 CDZ-73 Stuck Casing Plan Fod Maunder, Thomas E (©QA~ From.; Galiunas, Elizabeth C [Elizabeth.t/.Galiunas~conocophillps.com) Sent: Friday, Juty 10, 20091:21 PM To; Maunder, Thomas E (p4A); McKeever, Steve Cc: Anderson, Nina M; Alvord, Chtp Subject: RE: CD2-73 (208-196) Stuck Casing Plan t=orward Tom, Page 1 of 3 Per our conversation, we haue not been able to move the cut casing. The plan forward Is now as follows. 1, Pump cement per plan below to isolate the Qannik through the stage tool. Qannik Cement Job through stage tool: Dement from ports in a Stage tool at 8295' (KZ at 8371') to planned top of +/- 5fl0' above the Qannik interval with Class G + additives ~ 15.8 ppg. Assume 40% excess annular volume. Set as balance plug.. Hold pressure to keep cement in place. Lead: (8295'-7795') X 0,2146 ft3/ft X 1.4 (4fl% excess) = 160.22 fk3 annular vol. Total Volume = 150.22 ft3 _> 129 Sk ~ 1.17 ft3fsk System: 129 Sx Class G + fl.2% D046 antifoamer, fl.3q/o D~5 dispersant and 1 % Sfl02 accelerator ~ 15..8 PPG yielding 1.17 ft3lsk 2. RU and RtH with E-tine and radial cutting torch to cut casing right below the surface shoe. Run in with extra weight bar since we will not be able to circulate at this point. Cut the 7-5t8" casing at3800' (+f- 150' outside of surface shoe. 3657' MD). 3. If the radial cutting torch wit! not make tt to 3800', RIH to perforate casing for circulation to help the radial cutting torch reach 3800' Mp. 4. PODH with E-line tools and rig down E-line. 5. P©QH with 7-5/8". tnstatl thin wear bushing. Change top pipe rams to 3-112" to 6" variables. Test Rams to 3500 psi. 6. RIH with cement stringer on 5" DP to place cement from the casing stud up to 34fl0' (including 50' or sfl laid inside casing stub). This will bring cement back into the surface casing about 200' up from the shoe.. Pull up above TQC and circulate.. 7. PQOH and LD cement stinger. Pull thin wear bushing. 8. RIH with 5" I?P as kill string to 2000` MD. Cross over and land hanger. Pump diesel freeze protect... 9. LD drill pipe and move off weN for 8 days of rig maintenance. Resume operations after rig maintenance of pulling kill string and re-driAng the intermediate section. As Nina noted, the TD of the well will not changa. A sundry will be walked over this afternoon including all of the above information.. Call if you have any questions or comments. Regards, I_iz '7/1 U/24Q9 CD2-73 Stuck Casing Plan Fo~d l,iz Galiunas Alpine Drilling f:*rtginc~r CanocoPhillips Alaska Office: 907-26~-824' Cell: 907-903-1200 From: Maunder, Thomas E (DOA) (malto:tom.maunder@alaska.gov] Sent: Friday, July 1Q, ZQt?9 9:44 AM Ta: Oaliunas Elizabeth C McKeever, Steve Subject: FW: CD2-73 (2U8-196) Stuck Casing Rlan Forward from: Maunder, Thomas E (DOA) Sen#: Friday, July 1l), 2049 6:30 AM Ta: 'Anderson, Nina M' Cc: Wheatall, Michael, Alvord, Chip subject: RE: CD2-73 (2(}8-196) Stuck Casing Plan Forward Page 2 of 3 Frain: Anderson, Nina M [maHto:Nina.Anderson@conocophillips.com] Sent: Thursday, July i)9, 2Qt)9 4:48 PM To: Maunder, Thomas E (DOA) Cc: Wheatali, Michael; Alvord, ship Subject: CD2.-73 Stuck Casing Plan Forward Tom - As discussed this morning, Doyon 19 is on CD2~73. Vvhie running 7-5/8" intermediate casing, the casing shoe stopped at approximately +/- 17,162' MD. This depth is 654' from the planned casing point of 17,816' MD. It is suspected that the casing is stuck in the Kalubik shales which are found above the Alpine end Kuparuk sands. Throughout the tact 36 hours, the rig has had Tittle success getting the casing to move in either direction.. The well continues tp pack off at minimum circulating rates while attempting to reciprocate. To effectively abandon the well bore, the plan forward is to pump cement while we can sail[ circulate around the casing shoe. This cement will cover 5QQ' of annular space above the Kuparuk and Alpine sands with the top of cement estimated to be 16,64Q' MD. The top of Kuparuk is 17,280' MD. There is a minimum restriction in the Hallburton stage toot currently at 8295° MD that restricts the casing cutting tool from passing through. Therefore, the plan is to cut casing above the stage caller, lay in a viscous plug, and pump enough cement to provide isolation and a kick off plug. With the stage collar located +/- 654' of the Qannik reservoir, adequate moment will be placed above this hydrocarbon zone but not directly across the interval. The Qannik will be isolated from the 7l l o~2oas CD2-73 Stuck Casing Plan Fod . Page 3 of 3 lower Kuparuk and Alpine reservoirs from the cement placed around the shoe. The rig will be shut down within 8 days due to loss of power from the planned Alpine plant shut down. At this time, CD2-73 will be secured with cement plugs in place, kill weight mud, a kill string hung, a BPV set, and a tree. Doyon 19 will move off the well for annual rig maintenance to coincide with the shut down. Once complete, the rig will move back on the well to continue operations with a full BOPE test performed. The intermediate section will be sidetracked and redrilled. The final bottom hole location of the sidetracked well is planned to be the same as originally permitted in PTD 208-196. Per our discussion, the plug backed hole will be called CD2-73 Plugback 1. The sidetrack will retain the original name of CD2-73. To follow up, a Sundry will be submitted for the plug back operation along with a modified directional well plan and details of the cement operations. Attached are the following documents: Current Schematic of CD2-73 with actual depths Log showing estimated casing shoe Please let me know if further information is needed. Thanks. Nina Anderson Drilling Engineer Alpine Drilling Team Office: (907)-265-6403 Cell: (907) 575-3256 «CD2-73 Stuck Casing schematic.vs.pdfi> «CD2-73 casing problem.ppt» 7/10/2009 • CD2-73 Injection Well Stuck 7-5/8" Casing Updated 07/09/09 ACTUAL Top Alpine C 17763 MD / 7305 TVD Top Alpine 63 Top Alpine A Top Kuparuk 17280' MD I ~ ~ i - - 7240' TVD ~ ~ ~ ~ in the lower Alpine C sands ~L______~ 17,840'MD /7309'TVD CD2-7. 3" Casing at 62' M D Kuparuk SS U CD2-73 (PTD 208-196) ~J Maunder, Thomas E (DOA) From: Anderson, Nina M [Nina.Anderson@conocophillips.com] Sent: Friday, June 26, 2009 9:23 AM To: Maunder, Thomas E (DOA) Subject: RE: CD2-73 (PTD 208-196) Page 1 of 2 Tom - CPAI will continue drilling this will as stated in the PTD 208-196_ The rig will call 24 hrs before the expected BOPE test. We anticipate moving the rig on Monday. Thanks, Nina Anderson From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, June 25, 2009 4:10 PM To: Anderson, Nina M Cc: Doyon 19 Company Man; McKeever, Steve Subject: RE: CD2-73 (PTD 208-196) Nina, Thanks for meeting. I am surprised as well that neither of us has a paper trail on this one. The likelihood of shutting down at a casing point was clearly stated in the permit application letter. I remember that in fact operations were SD sometime in January as you noted in our conversation. Your proposed work is appropriate for resuming operations. Although not stated, I presume that CPAI will continue drilling CD2-73 as presently permitted and that the Inspector will be notified regarding the BOP test. A copy of this message should be available on the rig. Call or message with any questions. Tom Maunder, PE AOGCC From: Anderson, Nina M [mailto:Nina.Anderson@conocophillips.com] Sent: Thursday, June 25, 2009 2:57 PM To: Maunder, Thomas E (DOA) Cc: Doyon 19 Company Man; McKeever, Steve Subject: CD2-73 (PTD 208-196) Tom - Doyon 19 will be moving on to CD2-73 next week around June 30m. CD2-73 was temporarily shutdown with surface casing for CD3 ice road operations in January 2009. The 10-3/4" casing was cemented and pressure tested to 3500 psi for 30 minutes. The floats were checked following the plug being bumped. The wellbore currently contains a kill string to 2,046' MD. Please review the planned procedure below and let us know if this is acceptable. Thanks. 1. Before moving on CD2-73, confirm that a BPV is installed. 2. Move on Doyon 19. 3. Rig up over CD2-73, dewater cellar as required. 7/1/2009 CD2-73 (PTD 208-196) ~ ~ Page 2 of 2 4. Pull BPV. Circulate out diesel with 9.6 Brine. 5. Install two way check. 6. ND Tree. NU BOPE. Body test BOP and flange break. 7. Pull two way check. 8. Pressure test casing to 3500 psi for 10 minutes. 9. Pull tubing hanger to floor and stand back kill string. 10. Set test plug and test BOPE to 3500 psi. Nina Anderson Drilling Engineer Alpine Drilling Team Office: (907)-265-6403 Cell: (907) 575-3256 7/1/2009 • ConocoPhillips ~~ P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 19, 200 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ~~~~ .~ .4 MAR ~ ~a~ 9 Alaska Oif Gas oas. ~, ., 6;;u. ,~ Ancharae ~a~-~q~ G`~t ~- 7 3 Dear Mr. Maunder: f` Enclosed please find a spreadsheet with a list of wells from the Kuparuk field S~R~).' Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped March 16~' & 17~`, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ~, ~.~~- Perry Kleiri ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Alpine Field Date 3/19/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al CD2-72 207-057 SF NA 6" NA 0.85 3/17/2009 CD2-73 208-196 4'5" NA 4'5" NA 21.25 3/17/2009 CD2-75 208-064 SF NA 8" NA 1.70 3/17/2009 CD2-463 207-107 4' NA 4' NA 14.87 3/17/2009 CD2-464 208-082 6" NA 6" NA 1.70 3/17/2009 CD2-465 208-145 19" NA 19" NA 4.25 3/17/2009 CD2-466 208-095 8.5" NA 8'5" NA 1.70 3/16/2009 CD2-467 208-114 SF NA 6" NA 0.85 3/16/2009 CD2-468 208-180 SF NA 5" NA 1.70 3/17/2009 CD2-469 208-122 SF NA 7" NA 0.85 3/17/2009 CD2-470 208-129 SF NA 8" NA 1.70 3/17/2009 ~,ASiSA OiJU A1~D rirA,S COI~TSER~ATIOI~T COMD'IISSIOI~T M Chambers WNS Drilling Superintendent ConocoPhillips Alaska Inc. PO Box 100360 Anchorage AK 99510-0360 • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Colville River Field, Alpine Oil Pool, CD2-73 ConocoPhillips Alaska Inc. Permit No: 208-196 T11 N, R4E, UM Surface Location: 2210' FNL, 2003' FEL, SEC. 2, Bottomhole Location: 3329' FNL, 3290' FEL, SEC. 29, T12N, R4E, UM De2~r Mr. Chambers: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt yer f overnmental agent iesnand does not an approval required by law from oth g aui:horize conducting drilling operations the Commissioner serve Pthe~right to apj~rovals have been issued. In addition, withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with nlessl the Commiss~on~ Chapter 25 of the Alaska Administrative Code u licable specifically authorizes a varian ha ter 25 of the Alaska Administ ative Code, provision of AS 31.05, Title 20, p or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of th~pnrmit.anWhequP ed ae g contactothe representative of the Commission to Y Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, Cathy . Foerster ~ Commissioner DATED this ~ day of December, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ~~rl~ 1 a. Type of Work: 1 b. Current Well Class: Exploratory ^ Development OiI ^ 1 c. Specify if well is proposed for. Drill ^/ Re-drill Stratigraphic Test ^ Service Q Development Gas ^ Coalbed Methane ^ Gas Hydrates ^ Re-entry ^ Multiple Zon~ Single Zone Q Shale Gas ^ 2. Operator Name: 5. Bond: / Blanket Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 CD2-73 3. Address: 6. Proposed De ~ 1~r~ ~ 12. FieldlPool(S): 3l i P.O. Box 100360 Anchorage, AK 99510-0360 MD: TVD: 7292' Colville River Field 4a. location of Well (Governmental Section): 7. Property Designation: Surface: 2210' FNL, 2003' FEL, Sec 2, T11 N, R4E, UM ADL 360075, 387207, 387212, ASRCNPRA02 Alpine Oil Pool Top of Productive Horizon: 8. Land Use Permit 13. Approximate Spud Date: 2724' FNL, 764' FEL Sec 32, T12N, R4E, UM 380075 12/29/2008 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1.5 miles from Alpine PA 3329' FNL, 3290' FEL, Sec 29, T12N, R4E, UM 2560 4b. Location of Well (State Ba a Plane Coord~ ales): ~ ~` 1 a 10: KB Elevation 15. Distance to Nearest Surface: x- 3 0 ~ y- ~~~ Zone- 4 (Heignt above GL): L, 51.9' RB feet Well within Pool: CD2-59 845' at 17748' MD 16. Deviated wells: "~~ia~~i i'~ Kickoff depth: 400 ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90° deg Downhole: 3276 psig Surface: 2569 psig 18. Casing Program if ti S Setting Depth Quantity of Cement pec ica ons T B tt k f Size o om op s c. . or sac Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.5# H-40 Welded 77 37 37 114 114' pre-installed 13.5" 10-314" 45.5# L-80 BTCM 3663 37 37 3700 2400 743 sx ASL3, 270 sx 15.8 G G 875" 9 7-5/8" 29 7# L-80 BTCM 17711 37 37 17748 7311 . . 445 sx 15.8 cl G, 270 sx cl G for K2 6.75" 4.5" 12.6# L-80 IBT-M 16468 32 32 16500 6963 Tbg 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^ BOP Sketc~ Drilling Prograr^ Time v. Deptl~t Shallow Hazard Analysis / Property Plat ^ Diverter Sketcf^ Seabed Repor^ Drilling Fluid Pr / 20 AAC 25.050 requirements^ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact L. Galiunas c7Ff Printed Name ' M. Chamb rs Title WNS Drilling Superintendent Signature 0 ' Phone Date Commission Use Onty Permit to Drill API Number. Permit Approv / See cover letter Number: ~ ®~ - ~~ ~ 50- ~~~ ~Q ~Q ° ®~ Date: ~ ~~ /a~ for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed me ane, gas hydrates, or gas contained in shales: ~Ji~Vrc.1'~riwlCS.~V~t9 ~A~.C-~S.Q~S`~~~.~~ Samples req'd: Yes ^ No ~ Mud log req'd: Yes ^ No[i7f Other: M~r~ L ~~fal~~--r1~0 S H2S measures: Yes ^ No ~i Directional svy req'd: ~ No ^ 3S~ ~;\ ~"CD.°+~~5 ~ ~ ~ ~~ ~~ ~`i ~~ itiv ~G.~~,O.c"~~~--a ~ `~~ a,.C~Tf O~~G~\cs i.4: ~~a~Cx`CJCC~ U'3 ~ ~ \~'i ~~A- ~'~t~ ~ ~ ~ gppR DATE: ~~ ~ ~~ ~ ,~ ~.1 t 4 ~ t ~ ~ A~~=' [ „OVED THE COMMISSIOCOMMISSIONER STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL ~,., 20 AAC 25.005 1a. Type of Work: 1b. Current Well Class: Exploratory Development Oil ^ 1c. Specify if well is proposed for: Drill ^/ Re-drill Stratigraphic Test ^ Service /^ Development Gas ^ Coalbed Methane ^ Gas Hydrates ^ Re-entry ^ Multiple Zon~ Single Zone ^ Shale Gas ^ 2. Operator Name: 5. Bond: / Blanket Single Well 11. Well Na a and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 CD2-73 ` 3. Address: 6. Proposed Depth: ~ ~-3/I~~ ly~s 12. F~ /Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: TVD: 7292' olville River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 2210' FNL, 2003' FEL, Sec 2, T11 N, R4E, UM ADL 380075, 387207, 387212, ASRCNPRA02 Alpine Oil Pool • Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2724' FNL, 764' FEL Sec 32, T12N, R4E, UM 380075 12/29/2008 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1.5 miles from Alpine PA - 3329' FNL, 3290' FEL, Sec 29, T12N, R4E, UM • 2560 4b. Location of Well (State Base Plane Coordinates): ~?,/~~(Y"S 7 n•~s~a6 10. KB Elevation 15. Distance to Nearest ~~2n Surface: x- 3~ '31/,~„~•~i- 597 Zone- 4 (Height above GL): L, 51. B feet Well within Pool: CD2-59 845' at 17748' MD 16. Deviated wells: tl~lrj° Kickoff depth: 400 ft. 17. Maximum Anticipat ressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90° deg Downhole: 3276 tg' Surface: 2569 psig , 18. Casing Program ifi i S Setti epth Quantity of Cement ons pec cat T B tt k f Size om o op c. . or sac s Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.5# H-40 Welded 77 37 114 114' pre-installed 13.5" 10-3/4" 45.5# L-80 BTCM 3327 37 7 3364 2395 743 sx ASL3, 270 sx 15.8 cl G 9.875" 7-5/8" 29.7# L-80 BTCM 15661 37 37 15698 7366 445 sx 15.8 ct G, 270 sx G G for K2 6.75" 3.5" 9.3# L-80 EUE-M 15517 32 32 15549 7347 Tbg 6.75" 4.5" 12.6# L-80 IBTM 8369 15 8 7347 23567 7346 perforated and blank Liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) ective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD ND Conductor/structural - . y ~~'" "~,/~t Surface _~'~ `~ Intermediate ~ Production "•`•~~ Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^ B Sketcl^ Drilling Progra / Time v. Deptt~t Shallow Hazard Analysis / Property Plat ^ D~ rter Sketcf^ Seabed Repor^ Drilling Fluid Pr / 20 AAC 25.050 requirements /^ 21. Verbal Approval: Commission Represen ve: Date: 22. I hereby certify that the foregoing is tr and correct to the best of my knowledge. Contact L. Galiunas Printed Name M. ambers Title WNS Drilling Superintendent Signature Phone Date zG5-!3/ iz-iz-ob' Commission Use Only ~ Permit to Drill p R/ API Number: ~~rYr .~yAy~} Permit Approval See cover letter Number. ~IS l " Y 50- ~~~ ~ ~~ / / ~ ""'~ Date: for other requirements Conditions of appr al : If box is checked, well may not be used to explore for, test, or produce Coalbed me ane, gas hydrates, or gas contained in shales: Samples req'd: Yes ^ No ~ Mud log req'd: Yes ^ No~ Other: H2S measures: Yes ^ No ~ Directional svy req'd: ~eis, ~o ^ /~'' !s•~f•aS DATE: ~ f-{ ~ ~ , ~ ~ ~ ~ APPROVEb BY THE COMMISSION _ ,COMMISSIONER ~. ConocoPhillips Alaska, Inc. ~,,,. Post Office Box 100360 Anchorage, Alaska 99510-0360 ~QI'1(~C()P"1~~~~}~S Telephone 907-276-1215 December 12, 2008 x- Alaska Oil and Gas Conservation Commission 333-West 7th Avenue, Suite 100 .. _ Anchorage, Alaska 99501 Re: Application for Permit to Drill CD2-73 ~' ' Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Injectoion well from the CD2 drilling pad. The intended spud date for this well is 12/29/08. It is intended that Doyon Rig 19 be used to drill the well ' After setting 7-5/8" intermediate casing, the horizontal section will be drilled and the well completed with a perforated liner and tubing. At the end of the rig work program, the well will be flowed back for 2-3 days to mitigate reservoir damage. The well will then be closed in awaiting completion of well work and facilities connection that will allow the well to begin injection. It is very likely that due to ice road timing for CD3, operations on CD2-73 will be suspended at a casing point. In the case, a 10-403 package will be sent to the state indicating an operational shutdown. . It is expected that the K2 (Qannik) sand will be considered a significant hydrocarbon bearing zone. After running 7-5/8" casing, it is planned to pump lead cement, then open a stage tool and pump a second cement job to isolate the K2 with 500' of cement above and below the interval. This will leave a mud gap between the two stages. It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. At CD2, there has not been a significant show of shallow gas or gas hydrates through the surface hole interval " Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. A proposed drilling program. 3. A proposed completion diagram. 4. A drilling fluids program summary. 5. Pressure information as required by 20 ACC 25.035 (d)(2). 6. Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Riser setup If you have .any questions or require further. information, please contact Liz Galiunas, 265-6247, or Mark Chambers at 263-1319. Sincerely, Liz Galiunas Drilling Engineer Attachments cc: CD2-73 Well File /Sharon Allsup Drake ATO 1530 Mark Chambers ATO 1566 Nina Anderson ATO 1704 Tim Schnieder ATO 1706 Lanston Chin Kuukpik Corporation ~' CD2-73 Drilling Hazards Summary (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 13-1/2" Hole / 10-3/4" Casin Interval Event Risk Level Miti ation Strate Conductor Broach Low Monitor cellar continuous) durin interval. Well Collision Low G ro sin le shots, travelin c tinder dia rams Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud tem eratures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low Increased mud weight ' Surface Formations >2000' ND Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low densi cement slurries 9-7/8" Hole / 7-5/8" Casing Interval Event Risk Level Miti ation Strate Abnormal Pressure in low BOPE drills, Keep mud weight above 9.6 ppg. Surface Formations Check for flow during connections and if needed, >2000' TVD increase mud wei ht. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted swee s. - Abnormal Reservoir low Well control drills, increased mud weight. No Pressure mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low HZS drills, detection systems, alarms, standard well control ractices, mud scaven ers 6-3/4" Hole /Horizontal Production Hole Event Risk Level Miti ation Strate Lost circulation moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitorin ,wei hted swee s. Abnormal Reservoir Medium BOPE drills, Keep mud weight above 8.8 ppg. Pressure Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control ractices, mud scaven ers ORIGINAL Procedure 1. Move on Doyon 19. 2. Rig up riser, dewater cellar as needed. 3. Drill 13-1/2" hole to the surface casing point as per the directional plan. (Directional/MWD). 4. Run and cement 10-3/4" surface casing. 5. Install and test BOPE to 3500 psi. 6. Pressure test casing to 2500 psi. 7. Drill out 20' of new hole. Perform leak off test. 8. Pick up and run in hole with 9-7/8" drilling BHA. 9. Drill 9-7/8" hole to intermediate casing point in the Alpine A. (LWD Program: GR/RES/PWD) 10. Run and cement 7-5/8" casing as per program. Carry out a leak off test down the 10-3/4"x7-5/8" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 11. BOPE test to 3500 psi. 12. Drill 6-3/4" horizontal section to well TD (LWD Program: GR/RES/PWD). 13. Circulate the hole clean and pull out of hole. 14. Run 4-'/2, 12.6#, L-80 tubing with DB nipple, gas lift mandrel, packer, and XN nipple. Sting in, space out and land hanger. 15. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 16. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 17. Circulate tubing to diesel and install freeze protection in the annulus. 18. Drop ball and rod, set packer and test tubing and annulus to 3500 psi / 30 mins. 19. Set BPV and secure well. Move rig off. OR161~1AL Well Proximity Risks: U Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-72 is the nearest existing well to the CD2-73 plan at 13' well to well separation at 450' MD. Drilling Area Risks: There are no high-risk events. Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with lost circulation. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumping Operations: Incidental fluids developed from drilling operations on well CD2-73 will be injected into a permitted annulus on CD2, or the class 1 disposal well on CD1 pad. The CD2-73 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Qannik reservoir and there will be 500' of cement fill above the top of the Qannik as per regulations. Upon completion of CD2-73 form 10-403, Application for Sundry Operations, will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052)'' (Surf. Shoe TVD) + 1,500 psi _ (12.0 ppg} " (0.052) " (2400') + 1,500 psi = 2997 psi Pore Pressure = 1,131 psi Therefore Differential = 2997 -1131 = 1866 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 10-3/4" 45.5 L-80 3 BTC-M 2480 2108 psi 3580 psi 3043 psi 7-5f8" 29.7 L-80 3 BTC-M 4790 psi 4071 psi 6890 psi 5856 psi OR161N.AL DRILLING FLUID PROGRAM SPUD to 10-3/4"surface casing point -13- 1/2" Intermediate hole to 7- 5/8"" casing point - 9-7/8" Production Hole Section - 6 3/4" Density 8.8 - 9.6 ppg • 9.6 - 9.8 ppg 9.8-10.5 PP9 PV 10 - 25 10 -15 YP 20 - 60 15 - 25 25 - 30 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10 -15 10 minute gels <18 12 - 20 API Filtrate NC -10 cc / 30 min 4 -12 cc/30 min (drilling) HPHT Fluid Loss at 160 12 - 14 cc/30 min PH 8.5-9.0 9.0-10.0 9.0-9.5 KCL 6 Surface Hole: A standard high viscosity fresh water /gel spud mud is recommended for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel /polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Nechelik is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section The horizontal interval will be drilled with a M-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with ± 30PPB calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer and Dual-Flo starch will be used for viscosity and fluid loss control respectively. Higher mud weight due to offset injectors east of CD2-73. ^~IGINAL Comuletion Schematic Colville River Field CD2-73 Injection Well Completion 16" Conductor to 114' 4-1/2" Camco DB Nipple (3.812') at 1900' TVD = 2300' MD 10-3/4" 45.5 ppf L-80 BTC-mod Surface Casing 3700' MD / 2400' TVD cemented to surface Cement to +/- 786 ' MD / 3883' TVD Qannik interval top +/- 8361' MD / 4061' TVD f ;. H ES Stage Tool +/- ~ 8914' MD / 4259' TVD Camco KBG-2 GLM (3.909" DRIFT ID) w/ DCK2 SOV set for 2500 psi \ 16 TOC @ +/- 16100 MD 16821' 300' above packer depth Top Alpine D 17513 MD / 7283 TVD Top Alpine C 17550 MD / 7289 TVD Top Alpine A 17638 MD / 7301 TVD 7-5/8" 29.7 ppf L-80 BTC Mod Production Casing 17,748' MD / 7311' TVD Updated 12/11/08 Sperry Drilling WP04 Packer Fluid mix: Diesel in tubinq,and annulus Completion MD TVD Tubing Hanger 32' 32' 4-1/2", 12.6#!ft, IBT-Mod Tubing Camco D66 nipple 2300' 1900' 4-1/2", 12.6#!ft, IBT-Mod Tubing Camco KBG2-GLM (3.909" ID) w/ SOV 16338 6908' set for 2500 psi 4-1/2", 12.6#/ft, IBT-Mod Tubing (2) Baker Premier Packer 16438' 6941' 4-1/2", 12.6#/ft, IBT-Mod Tubing (1) HES "XN" (3.725")-69° inc 16488' 6959' 4-1/2", 12.6#/ft, IBT-Mod 10' pup joint WEG 16500' 6963' Well TD at 23,115' MD / 7291' TVD OR!GIN.4L PRESSURE INFORMATION (per 20 ACC 25.005 (c) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size in Csg Setting Depth MD/TVD ft Fracture Gradient lbs. / al Pore pressure si ASP Drilling si 16 114 / 114 10.9 52 53 10-3/4" 3700 / 2400 14.5 1086 1569 7-5/8" 17,748 / 7311 16.0 3308 2589 N/A 23,115 / 7291 16.0 3299 N/A • NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP. is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1 ]D Where: ASP =Anticipated Surface pressure in psi FG =Fracture gradient at the casing seat in Ib/gal 0.052 =Conversion from Ib./gal to psilft 0.1 =Gas gradient in psi/ft D =true Vertical depth of casing seat in ft RKB OR 2) ASP =FPP - (0.1 x D) Where; FPP =Formation Pore Pressure at the next casing point ASP CALCULATIONS Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1] D =[(10.9x0.052)-0.1]x114=53 psi OR ASP =FPP - (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi 2. Drilling below surface casing (10-3/4") ASP = [(FG x 0.052) - 0.1] D _ [(14.5 x 0.052) - 0.1] x 2400 = 1569 psi OR ASP =FPP - (0.1 x D) = 3308 - (0.1 x 7311) = 2576 psi Drilling below intermediate casing (7-5/8") ASP =FPP - (0.1 x D) = 3299 - (0.1 x 7291') = 2569 psi 01?!GINAL Cementing Program: 10-3/4" Surface Casing run to 3700' MD / 2400' TVD. Cement from 3700' MD to 3200' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 3200' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1717' MD). Lead slurry: (3200-1717') X 0.3637 ft3/ft X 1.5 (50% excess) = 809.1 ft3 below permafrost 1717' X 0.3637 ft3/ft X 4 (300% excess) = 2497.9 ft3 above permafrost Total volume = 809.1 + 2497.9 = 3306.9 ft3 => 743 Sx @ 4.45 ft3/sk System: 743 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOW' D044 freeze suppressant Tail slurry: 500' X 0.3637 ft3/ft X 1.5 (50% excess) = 272.8 ft3 annular volume 80' X 0.5397 ft3/ft = 43.1 ft3 shoe joint volume Total volume = 272.8 + 43.1 = 315.9 ft3 => 270 Sx @ 1.17 ft3/sk System: 270 Sx Class G + 0.2% D046 antifoamer, + 1%S2, 0.2%D46, 0.3%D65 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7-5/8" Intermediate Casing run to 17,748 MD / 7311' TVD Second Stage: Cement from 17,748' MD to 16100' MD (500' of Class G + adds @ 15.8 PPG and minimum 300' MD above the packer). Assume 40% excess annular volume. Lead: (17748'-16100 X 0.2146 ft3/ft X 1.4 (40% excess) = 495.1 ft3 annular vol. 80' X 0.2577 ft /ft = 20.6 ft3 shoe joint volume Total volume = 495.1 + 20.6 = 515.7 ft3 => 445Sx @ 1.16 ft3/sk System: 445 Sx Class G + Class G + 1 %S2, 0.2%D46, 0.3%D65 @ 15.8 PPG yielding 1.16 ft3/sk Second Stage: Cement from ports in a Stage tool set 500' below the K2 interval to +/- 500' above the K2 interval with Class G + additives @ 15.8 ppg. Assume 40% excess annular volume Lead: (8914'-7861') X 0.2146 ft3/ft X 1.4 (40% excess) = 316.4 ft3 annular vol. Total Volume = 316.4 ft3=> 270 Sk @ 1.17 ft3/sk System: 270 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1 % S002 accelerator @ 15.8 PPG yielding 1.17 ft3/sk By Weight Of mix Water, all other additiv~ ~~~er~ ~ ~ ConocoPhillips(Alaska) Inc. Western North Slope CD2 Alpine Pad Plan: CD2-73 Plan: CD2-73 Plan: CD2-73wp04 Standard Proposal Report 12 December, 2008 'H ' '~.1 'U T .Sperry Drilling :Services ORIGINAL WesteFn North Slope CD2 Alpine Pad Plan: CD2-73 Plan: CD2-73 CD2-73wp04 90~ .- c 0 0 M 60 L Z ~- 30 0 0 .-. c 2 ~ 30 0o h~o N 2500 .. --~ C-30 C-20 Q. N 10-3/4" x 13-1/2" 0 = -_ ____- _ ...................._._.. .f U Basal K-2e~ 5000 _~--,,----:_-..- ....._..... ____ __-.._---....- ~ Albian 97 ~ Albian 96 L H ~, , ,~, 7500 ~ Alpine A Sand'! J 0 2500 CD2-73wp04 7-5/8" X 9-7/8" 4-1/2" x 6-1/8" __ __ ~ ,_. ~ o 4' a' CD2-73wp04 T CD2 73wp04 Hee-If ~ 5000 7500 10000 12500 15000 0 Prtiral ~artinn at ~~d M°(7,(1(1 ft/inl ~~~~ °~~~~L -18000 -15000 -12000 -9000 -6000 -3000 0 West(-)/East(+) (3000 ftlin) ConocoPhillips .11 ~_ Standard Proposal Report 'Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan: CD2-73 Company: ConocoPhillips(Alaska) Inc. ND Reference: Plan: CD2-73 (36.3+15.6) @ 51.90ft (Doyon 19) Project: Western North Slope MD Reference: Plan: CD2-73 (36.3+15.6) @ 51.90ft (Doyon 19) Site: CD2 Alpine Pad North Reference: True Well: Plan: CD2-73 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD2-73 Design: CD2-73wp04 Project Western North Slope Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor i Site __- CD2 Alpine Pad -- - ~ -~.--- - Site Position: Northing: 5,984,677.62ft Latitude: 70° 22' 9.206 N From: Map Easting: 528,389.22ft Longitude: 149° 46' 9.484 W Position Uncertainty: 0.00 ft .Slot Radius: 0" Grid Convergence: 0.22 ° ~ Well Plarr CD2-73 Well Position +N/-S O.OOft Northing: 5,974,155.46ft ~ Latitude: 70° 20' 15.365 N +EI-W O.OOft Easting: 371,230.20ft Longitude: 151°2'41.450W Position Uncertai nty 0.00 ft Wellhead Elevation: ft Ground Level: 15.60ft Wellbore Plan: CD2-73 ..... x :, Magnetics Model Name Sample Date declination Dip',Anyle Field Strength BG(~IA20 07 12.!11/~OOg 16.74 ~'~ ~~0 57 56 - Design _~ _ CD2-73wp04 _- ... ;. Audit Notes: Version: Phase: PLAN Tie On Depth: 36.30 Vertical Section: Depth From (ND) +N/-S +E/.W Direction lft1 (ft} In) (°) 36.30 0.00 0.00 334.00 Plan Sections Measured Vertical " Np Dogleg Bu ild Turn Depth Inc lination Azimuth Depth System +N/-S +FJ-W Rate Rate Rate Tool Face .. (ft) (°) (~) (ft) ft (ft) (ftl (°/100ft) (°I1 00ft) (°J100ft) (~) 36.30 0.00 0.00 36.30 -15.60 0.00 0.00 0.00 0.00 0.00 .0.00 400.00 0.00 0.00 400.00 348.10 0.00 0.00 0.00 0.00 0.00 0.00 700.00 7.50 300.00 699.14 647.24 9.80 -16.98 2.50 2.50 0.00 . 300.00 1,000.00 16.94 323.71 992.17 940.27 54.94 -59.92 3.50 3.15 7.90 40.00 2,243.62 69.11 287.15 1,880.49 1,828.59 400.19 -780.47 4.50 4.20 -2.94 -42.18 17,057.07 69.11 287.15 7,162.21 7,110.31 4,482.09 -14,004.68 0.00 0.00 0.00 0.00 17,748.87 86.00 305.00 7,311.90 7,260.00 4~77g.77 -14,605.09 3.50 2.44 2.58 48.19 17,863.16 90.00 305.00 7,315.89 7,263.99 q,g45.27 -14,698.63 3.50 3.50 0.00 0.00 18,705.95 90.28 334.50 7,313.75 7,261.85 5,481.41 -15,237.20 3.50 0.03 3.50 89.42 23,115.77 90.28 334.50 7,291.90 7,240.00 9,461.49 -17,135.90 0.00 0.00 0.00 0.00 COMPASS 2003.16 Build 42F 12/12/2008 11:32:50AM a :: • ConocoPhillips Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Re#erence: Well Plan: CD2-73 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: CD2-73 (36.3+ 15.6) @ 51 .90ft (Doyon 19) Project: Western North Slope MD Reference: Plan: CD2-73 (36.3+ 15.6) @ 51 .90ft (Doyon 19) Site: CD2 Alpine P ad North Reference' True WeII; Plan: CD2-73 Survey Calculation M ethod: Minimum Curvature Wellbore: Plan: CD2-73 Design: CD2-73wp04 r-_ Planned Survey __ _ - - _ ~:- - Measured Vertical Map Map Depth In clination Az imuth Depth TVDss +N!-S +E/_yy Northiny Fasting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) Ift) (ft) -15.60 36.30 0.00 0.00 36.30 -15.60 0.00 0.00 5,974,155.46 371,230.'LO 0.00 0.00 100.00 0.00 0.00 100.00 48.10 0.00 0.00 5,974,155.46 371,230.20 0.00 0.00 200.00 0.00 0.00 200.00 148.10 0.00 0.00 5,974,155.46 371,230.20 0.00 0.00 300.00 0.00 0.00 300.00 248.10 0.00 0.00 5,974,155.46 371,230.20 0.00 0.00 400.00 0.00 0.00 400.00 348.10 0.00 0.00 5,974,155.46 371,230.20 0.00 0.00 Start Buil d 2.50 500.00 2.50 300.00 499.97 448.07 1.09 -1.89 5,974,156.58 371,228.33 2.50 1.81 600.00 5.00 300.00 599.75 547.85 4.36 -7.55 5,974,159.95 371,222.72 2.50 7.23 700.00 7.50 300.00 699.14 647.24 9.80 -16.98 5,974,165.55 371,213.39 2.50 16.25 Start DLS 3.50 TFO 40.00 800.00 10.43 312.52 797.92 746.02 19.18 -29.30 5,974,175.14 371,201.23 3.50 30.09 900.00 13.62 319.43 895.72 843.82 34.25 X3.64 5,974,190.45 371,187.16 3.50 49.91 1,000.00 16.94 323.71 992.17 940.27 54.94 -59.92 5,974,211.42 371,171.23 3.50 75.65 Start DLS 4.50 TFO -42.19 1,100.00 20.49 315.05 1,086.89 1,034.99 79.08 -80.92 5,974,235.91 371,150.66 4.50 106.55 1,200.00 24.35 308.95 1,179.33 1,127.43 104.44 -109.33 5,974,261.75 371,122.69 4.50 141.80 1,300.00 28.38 304.45 1,268.92 1,217.02 130.86 -144.98 5,974,288.77 371,087.50 4.50 181.17 1,400.00 32.53 301.01 1,355.11 1,303.21 158.17 -187.64 5,974,316.81 371,045.32 4.50 224.42 1,500.00 36.76 298.28 1,437.36 1,385.46 186.21 -237.06 5,974,345.70 370,996.39 4.50 271.29 1,600.00 41.03 296.04 1,515.18 1,463.28 214.81 -292.93 5,974,375.25 370,941.02 4.50 321.49 1,700.00 45.34 294.16 1,588.08 1,536.18 243.79 -354.91 5,974,405.29 370,879.56 4.50 374.70 1,800.00 49.68 292.53 1,655.61 1,603.71 272.97 -422.61 5,974,435.62 370,812.37 4.50 430.60 1,900.00 54.04 291.11 1,717.35 1,665.45 302.17 -495.62 5,974,466.07 370,739.88 4.50 488.85 2,000.00 58.41 289.83 1,772.93 1,721.03 331.21 -573.48 5,974,496.44 370,662.54 4.50 549.09 2,100.00 62.80 288.67 1,822.00 1,770.10 359.91 -655.72 5,974,526.55 370,580.81 4.50 610.94 2,200.00 67.19 287.60 1,864.26 1,812.36 388.10 -741.82 5,974,556.21 370,495.21 4.50 674.02 2,243.62 69.11 287.15 1,880.49 1,828.59 400.19 -780.47 5,974,568.96 370,456.78 4.50 701.82 2,243.65 69.11 287.15 1,880.50 1,828.60 400.20 -780.49 5,974,568.97 370,456.76 0.00 701.84 Start 148 13.39 hold at 2243.65 MD 2,300.00 69.11 287.15 1,900.59 1,848.69 415.73 -830.79 5,974,585.35 370,406.73 0.00 737.85 2,400.00 69.11 287.15 1,936.25 1,884.35 443.28 -920.07 5,974,614.44 370,317.96 0.00 801.75 2,500.00 69.11 287.15 1,971.90 1,920.00 470.84 -1,009.34 5,974,643.52 370,229.18 0.00 865.65 2,600.00 69.11 287.15 2,007.56 1,955.66 498.39 -1,098.61 5,974,672.60 370,140.40 0.00 929.55 2,700.00 69.11 287.15 2,043.:?1 1,991.31 525.95 -1,187.88 5,974,701.68 370,051.62 0.00 993.45 2,800.00 69.11 287.15 2,078.87 2,026.97 553.50 -1,277.15 5,974,730.76 369,962.84 0.00 1,057.35 2,900.00 69.11 287.15 2,114.52 2,062.62 581.06 -1,366.42 5,974,759.85 369,874.07 0.00 1,121.25 3,000.00 69.11 287.15 2,150.18 2,098.28 608.61 -1,455.70 5,974,788.93 369,785.29 0.00 1,185.15 3,100.00 69.11 287.15 2,185.83 2,133.93 636.17 -1,544.97 5,974,818.01 369,696.51 0.00 1,249.05 3,200.00 69.11 287.15 2,221.49 2,169.59 663.73 -1,634.24 5,974,847.09 369,607.73 0.00 1,312.96 3,300.00 69.11 287.15 2,257.14 2,205.24 691.28 -1,723.51 5,974,876.17 369,518.95 0.00 1,376.86 3,400.00 69.11 287.15 2,292.E10 2,240.90 718.84 -1,812.78 5,974,905.26 369,430.18 0.00 1,440.76 3,500.00 69.11 287.15 2,328.45 2,276.55 746.39 -1,902.05 5,974,934.34 369,341.40 0.00 1,504.66 3,600.00 69.11 287.15 2,364.'11 2,312.21 773.95 -1,991.33 5,974,963.42 369,252.62 0.00 1,568.56 3,700.00 69.11 287.15 2,399.76 2,347.86 801.50 -2,080.60 5,974,992.50 369,163.84 0.00 1,632.46 12/12/2008 11:32:50AM P e ~ ~ ~~ ~ L COMPASS 2003.16 Build 42F ~ ~ !,..t' Y18 ConocoPhillips . R - €~ ' ~ "'~ ~ Standard Proposal Report Database: EDM v16 Prod Local C o-ordinate Reference: Well Plan: CD2.73 Company: ConocoPhillip s(Alaska) Inc. ND Reference: Plan: CD2-73 (36.3+ 15.6) @ 51 .90ft (Doyon 19) Project: Western North Slope MD Reference: Plan: CD2-73 (36.3+ 15.6) @ 51 .90ft (Doyon 19) Site: CD2 Alpine P ad North R eference: True Well: Plan: CD2-73 Survey Calculation Method: Minim um Curvature Wellbore: Plan: CD2-73 Design: CD2-73wp04 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth:.. Depth. NDss +N/-S +E/-W .Northing Easting DLS Vert Section (ft) (`) (~) (ft) ft (ft) (~) ' (ft) lft) 2,348.10 3,700.67 69.11 287.15 2,400.00 2,348.10 801.69 -2,081.20 5,974,992.70 369,163.24 0.00 1,632.89 10-3/4" x 13-1/2" 3,725.63 69.11 287.15 2,408.90 2,357.00 808.57 -2,103.48 5,974,999.96 369,141.08 0.00 1,648.84 C-30 3,800.00 69.11 287.15 2,435.41 2,383.51 829.06 -2,169.87 5,975,021.58 369,075.06 0.00 1,696.36 3,900.00 69.11 287.15 2,471.07 2,419.17 856.61 -2,259.14 5,975,050.67 368,986.28 0.00 1,760.26 4,000.00 69.11 287.15 2,506.72 2,454.82 884.17 -2,348.41 5,975,079.75 368,897.51 0.00 1,824.16 4,100.00 69.11 287.15 2,542.38 2,490.48 911.72 -2,437.68 5,975,108.83 368,808.73 0.00 1,888.06 4,200.00 69.11 287.15 2,578.03 2,526.13 939.28 -2,526.96 5,975,137.91 368,719.95 0.00 1,951.96 4,300.00 69.11 287.15 2,613.69 2,561.79 966.83 -2,616.23 5,975,166.99 368,631.17 0.00 2,015.86 4,400.00 69.11 287.15 2,649.34 2,597.44 994.39 -2,705.50 5,975,196.08 368,542.39 0.00 2,079.76 4,500.00 69.11 287.15 2,685.00 2,633.10 1,021.94 -2,794.77 5,975,225.16 368,453.62 0:00 2,143.66 4,600.00 69.11 287.15 2,720.65 2,668.75 1,049.50 -2,884.04 5,975,254.24 368,364.84 0.00 2,207.57 4,700.00 69.11 287.15 2,756.31 2,704.41 1,077.06 -2,973.31 5,975,283.32 368,276.06 0.00 2,271.47 4,746.53 69.11 287.15 2,772.90 2,721.00 1,089.88 -3,014.86 5,975,296.85 368,234.75 0.00 2,301.20 C-20 4,800.00 69.11 287.15 2,791.96 2,740.06 1,104.61 -3,062.59 5,975,312.40 368,187.28 0.00 2,335.37 4,900.00 69.11 287.15 2,827.62 2,775.72 1,132.17 -3,151.86 5,975,341.49 368,098.50 0.00 2,399.27 5,000.00 69.11 287.15 2,863.27 2,811.37 1,159.72 -3,241.13 5,975,370.57 368,009.73 0.00 2,463.17 5,100.00 69.11 287.15 2,898.93 2,847.03 1,187.28 -3,330.40 5,975,399.65 367,920.95 0.00 2,527.07 5,200.00 69.11 287.15 2,934.58 2,882.68 1,214.83 -3,419.67 5,975,428.73 367,832.17 0:00 2,590.97 5,300.00 69.11 287.15 2,970.24 2,918.34 1,242.39 -3,508.94 5,975,457.81 367,743.39 0.00 2,654.87 5,400.00 69.11 287.15 3,005.89 2,953.99 1,269.94 -3,598.22 5,975,486.90 367,654.61 0.00 2,718.77 5,500.00 69.11 287.15 3,041.55 2,989.65 1,297.50 -3,687.49 5,975,515.98 367,565.83 0.00 2,782.67 5,600.00 69.11 287.15 3,077.20 3,025.30 1,325.05 -3,776.76 5,975,545.06 367,477.06 0.00 2,846.57 5,700.00 69.11 287.15 3,112.86 3,060.96 1,352.61 -3,866.03 5,975,574.14 367,388.28 0.00 2,910.47 5,800.00 69.11 287.15 3,148.51 3,096.61 1,380.16 -3,955.30 5,975,603.22 367,299.50 0.00 2,974.37 5,900.00 69.11 287.15 3,184.17 3,132.27 1,407.72 -4,044.57 5,975,632.31 367,210.72 0.00 3,038.28 6,000.00 69.11 287.15 3,219.82 3,167.92 1,435.28 -4,133.85 5,975,661.39 367,121.94 0.00 3,102.18 6,100.00 69.11 287.15 3,255.48 3,203.58 1,462.83 -4,223.12 5,975,690.47 367,033.17 0.00 3,166.08 6,200.00 69.11 287.15 3,291.13 3,239.23 1,490.39 -4,312.39 5,975,719.55 366,944.39 0.00 3,229.98 6,300.00 69.11 287.15 3,326.79 3,274.89 1,517.94 -4,401.66 5,975,748.63 366,855.61 0.00 3,293.88 6,400.00 69.11 287.15 3,362.44 3,310.54 1,545.50 -4,490.93 5,975,777.71 366,766.83 0.00 3,357.78 6,500.00 69.11 287.15 3,398.10 3,346.20 1,573.05 -4,580.20 5,975,806.80 366,678.05 0.00 3,421.68 6,600.00 69.11 287.15 3,433.75 3,381.85 1,600.61 -4,669.48 5,975,835.88 366,589.28 0.00 3,485.58 6,700.00 69.11 287.15 3,469.41 3,417.51 1,628.16 -4,758.75 5,975,864.96 366,500.50 0.00 3,549.48 6,800.00 69.11 287.15 3,505.06 3,453.16 1,655.72 -4,848.02 5,975,894.04 366,411.72 0.00 3,613.38 6,900.00 69.11 287.15 3,540.72 3,488.82 1,683.27 -4,937.29 5,975,923.12 366,322.94 0.00 3,677.28 7,000.00 69.11 287.15 3,576.37 3,524.47 1,710.83 -5,026.56 5,975,952.21 366,234.16 0.00 3,741.18 7,100.00 69.11 287.15 3,612.03 3,560.13 1,738.38 -5,115.83 5,975,981.29 366,145.38 0.00 3,805.08 7,200.00 69.11 287.15 3,647.68 3,595.78 1,765.94 -5,205.11 5,976,010.37 366,056.61 0.00 3,868.98 7,300.00 69.11 287.15 3,683.34 3,631.44 1,793.50 -5,294.38 5,976,039.45 365,967.83 0.00 3,932.89 7,400.00 69.11 287.15 3,718.99 3,667.09 1,821.05 -5,383.65 5,976,068.53 365,879.05 0.00 3,996.79 7,500.00 69.11 287.15 3,754.64 3,702.74 1,848.61 -5,472.92 5,976,097.62 365,790.27 0.00 4,060.69 7,600.00 69.11 287.15 3,790.30 3,738.40 1,876.16 -5,562.19 5,976,126.70 365,701.49 0.00 4,124.59 12/12/2008 11:32:50AM Page 4 COMPASS 2003.16 Build 42F ~ ~ 4 Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD2 Alpine Pad 'Wetl; Plan: CD2-73 Weflbore: - Plan: CD2-73 Design: CD2-73wp04 Planned Survey • ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: CD2-73 TVD Reference: Plan: CD2-73 (36.3+15.6) @ 51.90it (Doyon 19) MD Reference: --: Plan: CD2-73 (36.3+15.6) @ 51.90ft (Doyon 19) North Reference; True Survey Calculation Method: Minimum Curvature Measured Vertical Map Map Depth Inc{ina6on .Azimuth Depth NDss +N/-S +E/-W Northing Eastiny DLS Vert Section (ft) ( ~) (~) (#t) ft (ft) (ft) {ft) (ft) 3,774.05 7,700.00 69.11 287.15 3,825.95 3,774.05 1,903.72 -5,651.46 5,976,155.78 365,612.72 0.00 4,188.49 7,741.92 69.11 287.15 3,840.90 3,789.00 1,915.27 -5,688.88 5.976,167.97 365,575.50 0.00 4,215.27 K-3 Marker 7,800.00 69.11 287.15 3,861.61 3,809.71 1,931.27 -5,740.74 5,976,184.86 365,523.94 0.00 4,252.39 7,900.00 69.11 287.15 3,897.26 3,845.36 1,958.83 -5,830.01 5,976,213.94 365,435.16 0.00 4,316.29 8,000.00 69.11 287.15 3,932.92 3,881.02 1,986.38 -5,919.28 5,976,243.03 365,346.38 0.00 4,380.19 8,100.00 69.11 287.15 3,968.57 3,916.67 2,013.94 -6,008.55 5,976,272.11 365,257.60 0.00 4,444.09 8,200.00 69.11 287.15 4,004.23 3,952.33 2,041.49 -6,097.82 5,976,301.19 365,168.83 0.00 4,507.99 8,286.02 69.11 287.15 4,034.90 3,983.00 2,065.20 -6,174.62 5,976,326.21 365,092.46 0.00 4,562.96 Basal K-3 8,300.00 69.11 287.15 4,039.88 3,987.98 2,069.05 -6,187.09 5,976,330.27 365,080.05 0.00 4,571.89 8,361.75 69.11 287.15 4,061.90 4,010.00 2,086.06 -6,242.22 5,976,348.23 365,025.23 0.00 4,611.35 K-2 Marker 8,400.00 69.11 287.15 4,075.54 4,023.64 2,096.60 -6,276.37 5,976,359.35 364,991.27 0.00 4,635.79 8,500.00 69.11 287.15 4,111.19 4,059.29 2,124.16 -6,365.64 5,976,388.44 364,902.49 0.00 4,699.69 8,597.34 69.11 287.15 4,145.90 4,094.00 2,150.98 -6,452.54 5,976,416.74 364,816.07 0.00 4,761.90 Basal K-2 8,600.00 69.11 287.15 4,146.85 4,094.95 2,151.71 -6,454.91 5,976,417.52 364,813.71 0.00 4,763.59 8,700.00 69.11 287.15 4,182.50 4,130.60 2,179.27 -6,544.18 5,976,446.60 364,724.94 0.00 4,827.50 8,800.00 69.11 287.15 4,218.16 4,166.26 2,206.83 -6,633.45 5,976,475.68 364,636.16 0.00 4,891.40 8,900.00 69.11 287.15 4,253.81 4,201.91 2,234.38 -6,722.72 5,976,504.76 364,547.38 0.00 4,955.30 9,000.00 69.11 287.15 4,289.47 4,237.57 2,261.94 -6,812.00 5,976,533.85 364,458.60 0.00 5,019.20 9,100.00 69.11 287.15 4,325.12 4,273.22 2,289.49 -6,901.27 5,976,562.93 364,369.82 0.00 5,083.10 9,200.00 69.11 287.15 4,360.78 4,308.88 2,317.05 -6,990.54 5,976,592.01 364,281.04 0.00 5,147.00 9,300.00 69.11 287.15 4,396.43 4,344.53 2,344.60 -7,079.81 5,976,621.09 364,192.27 0.00 5,210.90 9,400.00 69.11 287.15 4,432.09 4,380.19 2,372.16 -7,169.08 5,976,650.17 364,103.49 0.00 5,274.80 9,500.00. 69.11 287.15 4,467.74 4,415.84 2,399.71 -7,258.35 5,976,679.26 364,014.71 0.00 5,338.70 9,600.00 69.11 287.15 4,503.40 4,451.50 2,427.27 -7,347.63 .5,976,708.34 363,925.93 0.00 5,402.60 9,700.00 69.11 287.15 4,539.05 4,487.15 2,454.82 -7,436.90 5,976,737.42 363,837.15 0.00 5,466.50 9,800.00 69.11 287.15 4,574.71 4,522.81 2,482.38 -7,526.17 5,976,766.50 363,748.38 0.00 5,530.40 9,900.00 69.11 287.15 4,610.36 4,558.46 2,509.93 -7,615.44 5,976,795.58 363,659.60 0.00 5,594.30 10,000.00 69.11 287.15 4,646:02 4,594.12 2,537.49 -7,704.71 5,976,824.67 .363,570.82 0.00. 5,658.20 10,100.00 69.11 287.15 4,681.67 4,629.77 2,565.05 -7,793.98 5,976,853.75 363,482.04 0.00 5,722.11 10,200.00. 69.11 287.15 4,717.33 4,665.43 2,592.60 -7,883.26 5,976,882.83 363,393.26 0.00 5,786.01 10,300.00 69.11 287.15 4,752.98 4,701.08 2,620.16 -7,972.53 5,976,911.91 363,304.49 0.00 5,849.91 10,400.00 69.11 287.15 4,788.64 4,736.74 2,647.71 -8,061.80 5,976,940.99 363,215.71 0.00 5,913.81 10,500.00 69.11 287.15 4,824.29 4,772.39 2,675.27 -8,151.07 5,976,970.07 363,126.93 0.00 5,977.71 10,600.00 69.11 287.15 4,859.95 4,808.05 2,702.82 -8,240.34 5,976,999.16 363,038.15 0.00 6,041.61 10,700.00 69.11 287.15 4,895.60 4,843.70 2,730.38 -8,329.61 5,977,028.24 362,949.37 0.00 6,105.51 10,800.00 69.11 287.15 4,931.26 4,879.36 2,757.93 -8,418.89 5,977,057.32 .362,860.59 0.00 6,169.41 10,900.00 69.11 287.15 4,966.91 4,915.01 2,785.49 -8,508.16 5,977,086.40 362,771.82 0.00 6,233.31 11,000.00 69.11 287.15 5,002.57 4,950.67 2,813.04 -8,597.43 5,977,115.48 362,683.04 0.00 6,297.21 11,100.00 69.11 287.15 5,038.22 4,986.32 2,840.60 -8,686.70 5,977,144.57 362,594.26 0.00 6,361.11 11,118.74 69.11 287.15 5,044.90 4,993.00 2,845.76 -8,703.43 5,977,150.02 362,577.63 0.00 6,373.08 Albian 97 12/12/2008 11:32:50AM Page 5 COMPASS 2003.16 Build 42F It Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope ..Site: CD2 Alpine Pad Well: Plan: CD2-73 Wellbore: Plan: CD2-73 `Design: CD2-73wp04 Planned Survey ConocoPhillips Standard Proposal Report local Co-ordinate Reference: Well Plan: CD2-73 TVD Reference: Plan: CD2-73 (36.3+15.6) @ 51.90ft (Doyon 19) MD Refierence: Plan: CD2-73 (36.3+15.6) @ 51.90ft (Doyon 19) North Reference: True Survey Calculation Method: Minimum Curvature Measured Vertical Map Map Depth incl ination Azimuth Depth TVDss +NI-S +E~_y~ Northing Easting DLS Vert Section (ft) (°) (~) (ft) ft (ft) (ft) (~) lft) 5,021.97 11,200.00 69.11 287.15 5,073.87 5,021.97 2,868.15 -8,775.97 5,977,173.65 362,505.48 0.00 6,425.01 11,300.00 69.11 287.15 5,109.53 5,057.63 2,895.71 -8,865.24 5,977,202.73 362,416.70 0.00 6,488.91 11,400.00 69.11 287.15 5,145.18 5,093.28 2,923.27 -8,954.52 5,977,231.81 362,327.93 0.00 6,552.82 11,500.00 69.11 287.15 5,180.84 5,128.94 2,950.82 -9,043.79 5,977,260.89 362,239.15 0.00 6,616.72 11,600.00 69.11 287.15 5,216.49 5,164.59 2,978.38 -9,133.06 5,977,289.98 362,150.37 0.00 6,680.62 11,700.00 69.11 287.15 5,252.15 5,200.25 3,005.93 -9,222.33 5,977,319.06 362,061.59 0.00 6,744.52 11,800.00 69.11 287.15 5,287.80 5,235.90 3,033.49 -9,311.60 5,977,348.14 361,972.81 0.00 6,808.42 11,900.00 69.11 287.15 5,323.46 5,271.56 3,061.04 -9,400.87 5,977,377.22 361,884.04 0.00 6,872.32 12,000.00 69.11 287.15 5,359.11 5,307.21 3,088.60 -9,490.15 5,977,406.30 361,795.26 0.00 6,936.22 12,100.00 69.11 287.15 5,394.77 5,342.87 3,116.15 -9,579.42 5,977,435.39 361,706.48 0.00 7,000.12 12,200.00 69.11 287.15 5,430.42 5,378.52 3,143.71 -9,668.69 5,977,464.47 361,617.70 0.00 7,064.02 12,300.00 69.11 287.15 5,466.08 5,414.18 3,171.26 -9,757.96 5,977,493.55 361,528.92 0.00 7,127.92 12,400.00 69.11 287.15 5,501.73 5,449.83 3,198.82 -9,847.23 5,977,522.63 361,440.14 0.00 7,191.82 12,500.00 69.11 287.15 5,537.39 5,485.49 3,226.37 -9,936.51 5,977,551.71 361,351.37 0.00 7,255.72 12,600.00 69.11 287.15 5,573.04 5,521.14 3,253.93 -10,025.78 5,977,580.80 361,262.59 0.00 7,319.62 12,700.00 69.11 287.15 5,608.70 5,556.80 3,281.49 -10,115.05 5,977,609.88 361,173.81 0.00 7,383.52 12,800.00 69.11 287.15 5,644.35 5,592.45 3,309.04 -10,204.32 5,977,638.96 361,085.03 0.00 7,447.43 12,900.00 69.11 287.15 5,680.01 5,628.11 3,336.60 -10,293.59 5,977,668.04 360,996.25 0.00 7,511.33 13,000.00 69.11 287.15 5,715.66 5,663.76 3,364.15 -10,382.86 5,977,697.12 360,907.48 0.00 7,575.23 13,100.00 69.11 287.15 5,751.32 5,699.42 3,391.71 -10,472.14 5,977,726.21 360,818.70 0.00 7,639.13 13,200.00 69.11 287.15 5,786.97 5,735.07 3,419.26 -10,561.41 5,977,755.29 360,729.92 0.00 7,703.03 13,202.60 69.11 287.15 5,787.90 5,736.00 3,419.98 -10,563.73 5,977,756.04 360,727.61 0.00 7,704.69 Albian 96 13,300.00 69.11 287.15 5,822.63 5,770.73 3,446.82 -10,650.68 5,977,784.37 360,641.14 0.00 7,766.93 13,400.00 69.11 287.15 5,858.28 5,806.38 3,474.37 -10,739.95 5,977,813.45 360,552.36 0.00 7,830.83 13,500.00 69.11 287.15 5,893.94 5,842.04 3,501.93 -10,829.22 5,977,842.53 360,463.59 0.00 7,894.73 13,600.00 69.11. 287.15 5,929.59 5,877.69 3,529.48 -10,918.49 5,977,871.62 360,374.81 0.00 7,958.63 13,700.00 69.11 287.15 5,965.25 5,913.35 3,557.04 -11,007.77 5,977,900.70 360,286.03 0.00 8,022.53 13,800.00 69.11 287.15 6,000.90 5,949.00 3,584.59 -11,097.04 5,977,929.78 360,197.25 0.00 8,086.43 13,900.00 69.11 287.15 6,036.56 5,984.66 3,612.15 -11,186.31 5,977,958.86 360,108.47 0.00 8,150.33 14,000.00 69.11 287.15 6,072.21 6,020.31 3,639.70 -11,275.58 5,977,987.94 360,019.70 0.00 8,214.23 14,100.00 69.11 287.15 6,107.87 6,055.97 3,667.26 -11,364.85 5,978,017.03 359,930.92 0.00 8,278.13 14,200.00 69.11 287.15 6,143.52 6,091.62 3,694.82 -11,454.12 5,978,046.11 359,842.14 0.00 8,342.04 14,300.00 69.11 287.15 6,179.18 6,127.28 3,722.37 -11,543.40 5,978,075.19 359,753.36 0.00 8,405.94 14,400.00 69.11 287.15 6,214.83 6,162.93 3,749.93 -11,632.67 5,978,104.27 359,664.58 0.00 8,469.84 14,500.00 69.11 287.15 6,250.49 6,198.59 3,777.48 -11,721.94 5,978,133.35 359,575.80 0.00 8,533.74 14,600.00 69.11 287.15 6,286.14 6,234.24 3,805.04 -11,811.21 5,978,162.43 359,487.03 0.00 8,597.64 14,700.00 69.11 287.15 6,321.80 6,269.90 3,832.59 -11,900.48. 5,978,191.52 359,398.25 0.00 8,661.54 14,800.00 69.11 287.15 6,357.45 6,305.55 3,860.15 -11,989.75 5,978,220.60 359,309.47 0.00 8,725.44 14,900.00 69.11 287.15 6,393.10 6,341.20 3,887.70 -12,079.03 5,978,249.68 359,220.69 0.00 8,789.34 15,000.00 69.11 287.15 6,428.76 6,376.86 3,915.26 -12,168.30 5,978,278.76 359,131.91 0.00 8,853.24 15,100.00 69.11 287.15 6,464.41 6,412.51 3,942.81 -12,257.57 5,978,307.84 359,043.14 0.00 .8,917.14 15,200.00 69.11 287.15 6,500.07 6,448.17 3,970.37 -12,346.84 5,978,336.93 358,954.36 0.00 8,981.04 15,300.00 69.11 287.15 6,535.72 6,483.82 3,997.92 -12,436.11 5,978,366.01 358,865.58 0.00 9,044.94 15,400.00 69.11 287.15 6,571.38 6,519.48 4,025.48 -12,525.38 5,978,395.09 358,776.80 0.00 9,108.84 12/12/2008 11:32:50AM ,P~e ~ ~ ~ COMPASS 2003.16 Build 42F Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD2 Alpine Pad Well: Plan: CD2-73 Wellbore: Plan: CD2-73 Design: CD2-73wp04 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: CD2-73 TVD Reference: Plan: CD2-73 (36.3+15.6) @ 51.90ft (Doyon 19) MD=Reference: Plan: CD2-73 (36.3+15.6) cQ 51.90ft (Doyon 19) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey Measured Vertical Depth Inclin ation Azimuth Depth TVDss +N/-S +E/-W (ft) (~ ) (~) (~) ft (ft) lft1 15,500.00 69.11 287.15 6,607.03 6,555.13 4,053.04 -12,614.66 15,600.00 69.11 287.15 6,642.69 6,590.79 4,080.59 -12,703.93 15,700.00 69.11 287.15 6,678.34 6,626.44 4,108.15 -12,793.20 15,800.00 69.11 287.15 6,714.00 6,662.10 4,135.70 -12,882.47 15,900.00 69.11 287.15 6,749.65 6,697.75 4,163.26 -12,971.74 16,000.00 69.11 287.15 6,785.31 6,733.41 4,190.81 -13,061.01 16,100.00 69.11 287.15 6,820.96 6,769.06 4,218.37 -13,150.29 16,200.00 69.11 287.15 6,856.62 6,804.72 4,245.92 -13,239.56 16,282.13 69.11 287.15 6,885.90 6,834.00 4,268.55 -13,312.87 HRZ 16,300.00 69.11 287.15 6,892.27 6,840.37 4,273.48 -13,328.83 16,400.00 69.11 287.15 6,927.93 6,876.03 4,301.03 -13,418.10 16,500.00 69.11 287.15 6,963.58 6,911.68 4,328.59 -13,507.37 16,600.00 69.11 287.15 6,999.24 6,947.34 4,356.14 -13,596.64 16,700.00 69.11 287.15 7,034.89 6,982.99 4,383.70 -13,685.92 16,795.38 69.11 287.15 7,068.90 7,017.00 4,409.98 -13,771.06 Base HRZ 16,800.00 69.11 287.15 7,070.55 7,018.65 4,411.26 -13,775.19 16,900.00 69.11 287.15 7,106.20 7,054.30 4,438.81 -13,864.46 16,944.03 69.11 287.15 7,121.90 7,070.00 4,450.94 -13,903.76 K-1 Marker 17,000.00 69.11 287.15 7,141.86 7,089.96 4,466.37 -13,953.73 17,057.04 69.11 287.15 7,162.19 7,110.29 4,482.08 -14,004.65 Start DLS 3.50 TFO 48.20 17,057.07 69.11 287.15 7,162.21 7,110.31 4,482.09 -14,004.68 17,100.00 70.12 288.34 7,177.16 7,125.26 4,494.36 -14,043.00 17,200.00 72.49 291.06 7,209.22 7,157.32 4,526.30 -14,132.16 17,212.34 72.78 291.39 7,212.90 7,161.00 4,530.57 -14,143.13 LCU-Miluvea ch 17,300.00 74.90 293.71 7,237.30 7,185.40 4,562.86 -14,220.88 17,400.00 77.34 296.30 7,261.30 7,209.40 4,603.90 -14,308.84 17,416.70 77.75 296.72 7,264.90 7,213.00 4,611.18 -14,323.44 Miluveach A 17,500.00 79.80 298.83 7,281.12 7,229.22 4,649.25 -14,395.71 17,516.00 80.19 299.24 7,283.90 7,232.00 4,656.90 -14,409.49 Alpine D 17,552.94 81.11 300.16 7,289.90 7,238.00 4,674.96 -14,441.15 Alpine C 17,600.00 82.28 301.33 7,296.70 7,244.80 4,698.76 -14,481.17 17,641.49 83.31 302.36 7,301.90 7,250.00 4,720.48 -14,516.14 Alpine A Sand 17,700.00 84.78 303.80 7,307.97 7,256.07 4,752.24 -14,564.89 17,748.87 86.00 305.00 7,311.90 7,260.00 4,779.77 -14.605.09 CD2-73wp04 Heel Map Map Northing Easting DLS Vert Section (ft) (ft) 6,555.13 5,978,424.17 358,688.02 0.00 9,172.74 5,978,453.25 358,599.25 0.00 9,236.65 5,978,482.34 358,510.47 0.00 9,300.55 5,978,511.42 358,421.69 0.00 9,364.45 5,978,540.50 358,332.91 0.00 9,428.35 5,978,569.58 358,244.13 0.00 9,492.25 5,978,598.66 358,155.35 0.00 9,556.15 5,978,627.75 358,066.58 0.00 9,620.05 5,978,651.63 357,993.67 0.00 9,672.53 5,978,656.83 357,977.80 0.00 9,683.95 5,978,685.91 357,889.02 0.00 9,747.85 5,978,714.99 357,800.24 0.00 9,811.75 5,978,744.07 357,711.46 0.00 9,875.65 5,978,773.16 357,622.69 0.00 9,939.55 5,978,800.89 357,538.01 0.00 10,000.50 5,978,802.24 357,533.91 0.00 10,003.45 5,978,831.32 357,445.13 0.00 10,067.36 5,978,844.12 357,406.04 0.00 10,095.49 5,978,860.40 357,356.35. 0.00 10,131.26 5,978,876.99 357,305.71 0.00 10,167.70 5,978,877.00 357,305.68 0.00 10,167.73 5,978,889.92 357,267.58 3.50 10,195.55 5,978,923.39 357,179.00 3.50 10,263.35 5,978,927.84 357,168.10 3.50 10,271.99 5,978,961.46 357,090.92 3.50 10,335.10 5,979,004.00 357,003.68 3.50 10,410.54 5,979,011.53 356,989.22 3.50 10,423.48 5,979,050.84 356,917.61 3.50 10,489.39 5,979,058.72 356,903.97 3.50 10,502.30 5:979,077.32 356,872.62 3.50 10,532.41 5,979,101.80 356,833.02 3.50 10,571.35 5,979,124.12 356,798.44 3.50 10,606.20 5,979,156.71 356,750.24 3.50 10,656.12 5,979,184.92 356,710.52 3.50 10,698.48 12/12/2008 11:32:50AM Page 7 ~~~E~~.~ COMPASS 2003.16 Build 42F Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD2 Alpine Pad VI/e1L• Plan: CD2-73 Wellbore: Plan: CD2-73 Design: CD2-73wp04 Planned Survey Measured Vertical Depth Inclination .Azimuth Depth (ft) (~) {') (~) 17 ~ 48.95 86.00 305.00 7,311.91 Start Bu ild 3.50 - 7-5/ 8" X 9-7/8" 17,800.00 87.79 305.00 7,314.67 17,863.16 90.00' 305.00 7,315.89 17,863.24 90.00 305.00 7,315.89 Start DLS 3.50 TFO 8 9.42 17,900.00 90.01 306.29 7,315.88 18,000.00 90.05 309.79 7,315.83 18,100.00 90.08 313.29 7,315.72 18,200.00 90.12 316.79 7,315.54 18,300.00 90.15 320.29 7,315.30 18,400.00 90.19 323.79 7,315.01 18,500.00 90.22 327.29 7,314.66 18,600.00 90.25 330.79 7,314.25 18,700.00 90.28 334.29 7,313.78 18,705.86 90.28 334.49 7,313.75 Start 4409.95 hold at 18705.86 MD 18,705.95 90.28 334:50 7,313.75 18,800.00 90.28 334.50 7,313.29 18,900.00 90.28 334.50 7,312.79 19,000.00 90.28 334.50 7,312.30 19,100.00 90.28 334.50 7,311.80 19,200.00 90.28 334.50 7,311.30 19,300.00 90.28 334.50 7,310.81 19,400.00 90.28 334.50 7,310.31 19,500.00 90.28 334.50 7,309.82 19,600.00 90.28 334.50 7,309.32 19,700.00 90.28 334.50 7,308.83 19,800.00 90.28 334.50 7,308.33 19,900.00 90.28 334.50 7,307.84 20,000.00 90.28 334.50 7,307.34 20,100.00 90.28 334.50 7,306.84 20,200.00 90.28 334.50 7,306.35 20,300.00 90.28 334.50 7,305.85 20,400.00 90.28 334.50 7,305.36 20,500.00 90.28 334.50 7,304.86 20,600.00 90.28 334.50 7,304.37 20,700.00 90.28 334.50 7,303.87 20,800.00 90.28 334.50 7,303.38 20,900.00 90.28 334.50 7,302.88 21,000.00 90.28 334.50 7,302.38 21,100.00 90.28 334.50 7,301.89 21,200.00 90.28 334.50 7,301.39 21,300.00 90.28 334.50 7,300.90 21,400.00 90.28 334.50 7,300.40 ConocoPhillips Standard Proposal Report Local Co-ord'+nate Reference: Well Plan: CD2-73 TVD Reference: Plan: CD2-73 (36.3+15.6) @ 51.90ft (Doyon 19) MD Reference: Plan: CD2-73 (36.3+15.6) @ 51.90ft (Doyon 19) North Reference: True Survey Calculation Method: Minimum Curvature TVDss +NI~S +6'-W ft (ft) (ft) 7,260.01 4,779.81 -14,605.15 Map Map Northing `:`Fasting (ft) ' (ft) 5,979,184.96 356,710.46 DLS Vert Section 7,260.01 0.00 10,698.54 7,262.77 4,809.05 -14,646.91 5,979,214.91 356,669.22 3.51 10,743.12 7,263.99 4,845.27 -14,698.63 5,979,252.01 356,618.13 3.50 10,798.35 7,263.99 4,845.31 -14,698.69 5,979,252.05 356,618.07 0.00 10,798.42 7,263.98 4,866.73 -14,728.57 5,979,273.98 356,588.57 3.51 10,830.77 7,263.93 4,928.34 -14,807.31 5,979,336.93 356,510.90 3.50 10,920.67 7,263.82 4,994.65 -14,882.15 5,979,404.50 356,437.21 3.50 11,013.07 7,263.64 5,065.39 -14,952.80 5,979,476.45 356,367.79 3.50 11,107.62 7,263.40 5,140.32 -15,019.01 5,979,552.50 356,302.89 3.50 11,203.99 7,263.11 5,219.15 -15,080.51 5,979,632.36 356,242.76 3.50 11,301.80 7,262.76 5,301.59 -15,137.08 5,979,715.75 356,187.61 3.50 11,400.70 7,262.35 5,387.33 -15,188.52 5,979,802.36 356,137.66 3.50 11,500.31 7,261.88 5,476.04 -15,234.63 5,979,891.84 356,093.08 3.50 11,600.26 7,261.85 5,481.33 -15,237.16 5,979,897.17 356,090.64 3.50 11,606.12 7,261.85 5,481.41 -15,237.20 5,979,897.25 356,090.60 3.50 11,606.21 7,261.39 5,566.29 -15,277.70 5,979,982.81 356,051.58 0.00 11,700.25 7,260.89 5,656.55 -15,320.75 5,980,073.79 356,010.08 0.00 11,800.25 7,260.40 5,746.80 -15,363.81 5,980,164.76 355,968.58 0.00 11,900.24 7,259.90 5,837.06 -15,406.87 5,980,255.73 355,927.09 0.00 12,000.24 7,259.40 5,927.31 -15,449.92 5,980,346.71 355,885.59 0.00 12,100.23 7,258.91 6,017.57 -15,492.98 5,980,437.68 355,844.09 0.00 12,200.23 7,258.41 6,107.82 -15,536.03 5,980,528.65 355,802.60 0.00 12,300.22 7,257.92 6,198.08 -15,579.09 5,980,619.63 355,761.10 0.00 12,400.22 7,257.42 6,288.33 -15,622.15 5,980,710.60 355,719.60 0.00 12,500.21 7,256.93 6,378.59 -15,665.20 5,980,801.57 355,678.11 0.00 12,600.21 7,256.43 6,468.84 -15,708.26 5,980,892.55 355,636.61 0.00 12,700.20 7,255.94 6,559.10 -15,751.31 5,980,983.52 355,595.11 0.00 12,800.20 7,255.44 6,649.35 -15,794.37 5,981,074.49 355,553.62 0.00 12,900.19 7,254.94 6,739.61 -15,837.43 5,981,165.47 355,512.12 0.00 13,000.19 7,254.45 6,829.86 -15,880.48 5,981,256.44 355,470.62 0.00 13,100.18 7,253.95 6,920.12 -15,923.54 5,981,347.41 355,429.13 0.00 13,200.18 7,253.46 7,010.37 -15,966.59 5,981,438.39 355,387.63 0.00 13,300.17 7,252.96 7,100.63 -16,009.65 5,981,529.36 355,346.13 0.00 13,400.17 7,252.47 7,190.88 -16,052.71 5,981,620.33 355,304.64 0.00 13,500.16 7,251.97 7,281.14 -16,095.76 5,981,711.31 355,263.14 0.00 13,600.16 7,251.48 7,371.39 -16,138.82 5,981,802.28 355,221.64 0.00 13,700.15 7,250.98 7,461.64 -16,181.88 5,981,893.26 355,180.15 0.00 13,800.15 7,250.48 7,551.90 -16,224.93 5,981,984.23 355,138.65 0.00 13,900.14 7,249.99 7,642.15 -16,267.99 5,982,075.20 355,097.15 0.00 14,000.14 7,249.49 7,732.41 -16,311.04 5,982,166.18 355,055.66 0.00 14,100.13 7,249.00 7,822.66 -16,354.10 5,982,257.15 355,014.16 0.00 14,200.13 7,248.50 7,912.92 -16,397.16 5,982,348.12 354,972.67 0.00 14,300.12 12/12/2008 11:32:50AM Page 8 COMPASS 2003.16 Build 42F '~ Database: EDM v16 Prod Local Co-ordinate Reference Company: ConocoPhillips(Alaska) Inc. TVD Reference: Project: Western North Slope MD Reference: Site: CD2 Alpine Pad North Reference: 1NelL• Plan: CD2-73 Survey Calculation Method: ConocoPhillips Standard Proposal Report Well Plan: CD2-73 Plan: CD2-73 (36.3+15.6) @ 51.90ft (Doyon 19) ', Plan: CD2-73 (36.3+15.6) @ 51.90ft (Doyon 19) ''' True Minimum Curvature Wellbore: Plan: CD2-73 Design: CD2-73wp04 ___ ~ Planned Survey __ Measured Vertical Map Map Depth Inclination Azi muth Depth TVDss +N!-S +E/-W Northing Easting DLS Vert Section (ft) ~ (°) (°) (ft) ft (ft) x. (ft) (ft) lft) 7,248.01 21,500.00 90.28 334.50 7,299.91 7,248.01 8,003.17 -16,440."21 5,982,439.10 354,931.17 0.00 14,400.12 21,600.00 90.28 334.50 7,299.41 7,247.51 8,093.43 -16,483.27 5,982,530.07 354,889.67 0.00 14,500.11 21,700.00 90.28 334.50 7,298.92 7,247.02 8,183.68 -16,526.32 5,982,621.04 354,848.18 0.00 14,600.11 21,800.00 90.28 334.50 7,298.42 7,246.52 8,273.94 -16,569.38 5,982,712.02 354,806.68 0.00 14,700.10 21,900.00 90.28 334.50 7,297.92 7,246.02 8,364.19 -16,612.44 5,982,802.99 354,765.18 0.00 14,800.10 22,000.00 90.28 334.50 7,297.43 7,245.53 8,454.45 -16,655.49 5,982,893.96 354,723.69 0.00 14,900.09 22,100.00 90.28 334.50 7,296.93 7,245.03 8,544.70 -16,698.55 5,982,984.94 354,682.19 0.00 15,000.09 22,200.00 90.28 334.50 7,296.44 7,244.54 8,634.96 -16,741.61 5,983,075.91 354,640.69 0.00 15,100.08 22,300.00 90.28 334.50 7,295.94 7,244.04 8,725.21 -16,784.66 5,983,166.88 354,599.20 0.00 15,200.08 22,400.00 90.28 334.50 7,295.45 7,243.55 8,815.47 -16,827.72 5,983,257.86 354,557.70 0.00 15,300.07 22,500.00 90.28 334.50 7,294.95 7,243.05 8,905.72 -16,870.77 5,983,348.83 354,516.20 0.00 15,400.07 22,600.00 90.28 334.50 7,294.46 7,242.56 8,995.98 -16,913.83 5,983,439.80 354,474.71 0.00 15,500.06 22,700.00 90.28 334.50 7,293.96 7,242.06 9,086.23 -16,956.89 5,983,530.78 354,433.21 0.00 15,600.06 22,800.00 90.28 334.50 7,293.46 7,241.56 9,176.49 -16,999.94 5,983,621.75 354,391.71 0.00 15,700.05 22,900.00 90.28 334.50 7,292.97 7,241.07 9,266.74 -17,043.00 5,983,712.72 354,350.22 0.00 15,800.05 23,000.00 90.28 334.50 7,292.47 7,240.57 9,356.99 -17,086.05 5,983,803.70 354,308.72 0.00 15,900.04 23,100.00 90.28 334.50 7,291.98 7,240.08 9,447.25 -17,129.11 5,983,894.67 354,267.22 0.00 16,000.04 ' 23,115.77 90.28 334.50 7,291.90 7,240.00 9,461.49 -17,135.90 5,983,909.02 354,260.68 0.00 16,015.81 CD2-73wp04 Toe Ta ryets Target Name - hitlmiss target Dip Angle D ip Dir. TVD +N!-S +E!-W Northi ng E asting -Shape (~) ~ (~) lft) (ft) (ft) (ft) Ift) CD2-73wp04 Toe 0.00 0.00 7,291.90 9,461.49 -17,135.90 5,983, 909.02 354,260.68 - plan hits target -Circle (radius 0.00) CD2-73wp04 Heel- 0.00 0.00 7,311.90 4,779.77 -14,605.09 5,979, 184.92 356,710.52 - plan hits target -Circle (radius 0.00) Casing Points I ___ > • a Measured Vertlcal Casing Hole Depth De pth Diameter Diameter .. (ft) (ft) Name (..) ~ ) 3,700.67 2,400.0() 10- 3l4" x 13-1/2" 10-3/4 13-1/2 17,748.95 7, 311.91 7-5/8" X 9-7/8" 7-5/8 9-7/8 23,115.80 4-1 /2" x 6-1/8" 4-1/2 6-1/8 12/12/2008 11:32:50AM ~,,~ ~ Page 9 COMPASS 2003.16 Build 42F „~~~~~~ S ConocoPhitlips Standard Proposal Report Database: EDM v16 Prod local Co-ordinate Reference: Well Plan: CD2-73 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: CD2-73 (36.3+15.6) @ 51.90ft (Ooyon 19) Project: Western North Slope MD Reference: Plan: CD2-73 (36.3+15.6) @ 51.90ft (Doyon 19) Site: CD2 Alpine Pad North Reference: True Well: Plan: CD2-73 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD2-73 Design: CD2-73wp04 Formations Measured Vertical Vertical Dip Depth Depth DepttY`SS Dip Direction (ft) (ft) ft Name ~ Lithology (°) (~) 7,741.92 3,840.90 K-3 Marker 16,944.03 7,121.90 K-1 Marker 11,118.74 5,044.90 Albian 97 17,516.00 7,283.90 Alpine D 16,282.13 6,885.90 HRZ 8,286.02 4,034.90 Basal K-3 8,597.34 4,145.90 Basal K-2 8,361.75 4,061.90 K-2 Marker 17,212.34 7,212.90 LCU-Miluveach 3,725.63 2,408.90 C-30 16,795.38 7,068.90 Base HRZ 17,552.94 7,289.90 Alpine C 13,202.60 5,787.90 Albian 96 17,416.70 7,264.90 Miluveach A 4,746.53 2,772.90 C-20 17,641.49 7,301.90 Alpine A Sand ... Plan Annotations Measured Vertical Local Co ordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ftl Comment 400.00 400.00 0.00 0.00 Start Build 2.50 700:00 699.14 9.80 -16.98 Start DLS 3.50 TFO 40.00 1,000.00 992.17 54.94 -59.92 Start DLS 4.50 TFO -42.19 2,243.65 1,880.50 400.20 -780.49 Start 14813.39 hold at 2243.65 MD 17,057.04 7,162.19 4,482.08 -14,004.65 . Start DLS 3.50 TFO 48.20 17,748.95 7,311.91 4,779.81 -14,605.15 Start Build 3.50 17,863.24 7,315.89 4,845.31 -14,698.69 Start DLS 3.50 TFO 89.42 18,705.86 7,313.75 5,481.33 -15,237.16 Start 4409.95 hold at 18705.86 MD 23,115.80 TD at 23115.80 12/12/2008 11:32:50AM Page 10 COMPASS 2003.16 Build 42F ~`(~~~ ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD2 Alpine Pad Plan: CD2-73 Plan: CD2-73 CD2-73wp04 ~a~r~r riin r~ri Clearance Summary Anticollision Report 12 December, 2008 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD2 Alpine Pad -Plan: CD2-73 -Plan: CD2-73 -CD2-73wp04 Well Coordinates: 5,973,902.15 N, 1,511,262.95E (70° 20' 14.18" N, 151° 02' 52.77" W) Datum Height: Plan: CD2-73 (36.3+15.6) @ 51.90ft (Doyon 19) Scan Range: 0.00 to 23,115.80 ft. Measured Depth. Scan Radius is 2,507.95 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42F Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 ..: " ~ . »~ . ''AL.LIB 'TON Sperry Drilling Services. CD2-7~wp04 36.30 To 23115.80 CD2-468wp05 GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 36 250 500 750 `, 0 / 360 1000 Rig: CD2-468 CD2-465 lsoo _ _ _ 30 7 330 , _ 90 ran[~_n~ -90 try, ~, ~~~ -- `CD2-31 Ri CD2-468 ~~~- CD2-75 -1~Q / 180 ~' -180 / 180 ~~ CD2-467 CD2-468wp05 CD2-470 CD2-469 CD2-467PB1 CD2-74wp03 i .~- s,, ut-r ~ -120 / 240 /~ ~` ~ ~'' ~ CD2-18PB1 `'-/.~ `~~ ; F g "`~~ -120 / 240 ~ it \ F , ,~~~,~ ~,% ~ , r ~'' ~ CD2-18 ~~ F ,~ ,~ - ti ,~!;' ~ CD2-74wp03 ----- ~~' " ~~ ~~ ~ ~ _CD2-31PB1 -150/210,., '~c'®f,`'~^~ ~ ~i~~ , ,~50---- ~ - -150/21 nder Azimuth (TFO+AZI) [9 vs Centre to Centre Separation [100 fUin] "~T,,,~ 120 50 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre 1 1 Ellipsoid Color 250 1750 2000 5000 6000 14000 500 2000 2500 6000 7000 16000 750 2500 3000 7000 8000 18000 1000 3000 3500 8000 9000 20000 1250 3500 "° " 4000 9000 ""°° 10000 1500 4000 4500 10000 .12000 1750 4500 5000 12000 14000 ~~' ,~ ConocoPhillips(Alaska) Inc. -WNS Western North Slope Anticollision Report for Plan: CD2-73 -CD2-73wp04 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD2 Alpine Pad -Plan: CD2-73 -Plan: CD2-73 -CD2-73wp04 Scan Range: 0.00 to 23,115.80 ft. Measured Depth. Scan Radius is 2,507.95 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name -Design (ft) (ft) (ft) (ft) ft CD2 Alpine Pad CD2-05 -CD2-05 -CD2-05 1,755.68 261.78 1,755.68 230.97 2,075.00 8.498 Clearance Factor Pass -Major Risk CD2-05 -CD2-05L1 -CD2-05L1 1,755.68 261.78 1,755.68 230.97 2,075.00 8.498 Clearance Factor Pass -Major Risk CD2-18 -CD2-18 -CD2-18 2,391.18 96.01 2,391.18 41.00 2,550.00 1.745 Clearance Factor Pass -Major Risk CD2-18 -CD2-18 -CD2-18 2,414.21 95.48 2,414.21 41.47 2,575.00 1.768 Centre Distance Pass -Major Risk CD2-18 -CD2-18P61 -CD2-18PB1 2,392.26 96.86 2,392.26 41.59 2,550.00 1.753 Clearance Factor Pass -Major Risk CD2-18 -CD2-18P61 -CD2-18PB1 2,415.59 96.52 2,415.59 42.22 2,575.00 1.778 Centre Distance Pass -Major Risk CD2-24 -CD2-24 -CD2-24 2,000.00 479.43 2,000.00 434.39 2,375.00 10.646 Centre Distance Pass -Major Risk CD2-24 -CD2-24 -CD2-24 2,016.94 479.54 2,016.94 434.15 2,400.00 10.565 Clearance Factor Pass -Major Risk CD2-24 -CD2-24P61 -CD2-24PB1 2,000.00 479.43 2,000.00 434.39 2,375.00 10.646 Centre Distance Pass -Major Risk CD2-24 -CD2-24PB1 -CD2-24P61 2,016.94 479.54 2,016.94 434.15 2,400.00 10.565 Clearance Factor Pass -Major Risk CD2-30 -CD2-30 -CD2-30 1,438.78 313.36 1,438.78 286.82 1,675.00 11.805 Clearance Factor Pass -Major Risk 1,991.90 109.18 1,991.90 76.30 2,275.00 3.321 Centre Distance Pass -Major Risk 2,013.57 110.22 2,013.57 76.24 2,300.00 3.244 Clearance Factor Pass -Major Risk 1,991.90 109.18 1,991.90 76.30 2,275.00 3.321 Centre Distance Pass -Major Risk 2,013.57 110.22 2,013.57 76.24 2,300.00 3.244 Clearance Factor Pass -Major Risk 1,345.84 440.29 1,345.84 415.70 1,575.00 17.909 Centre Distance Pass -Major Risk 1,361.44 440.46 1,361.44 415.64 1,600.00 17.746 Clearance Factor Pass -Major Risk ,.., CD2-31 -CD2-31 -CD2-31 ~, CD2-31 -CD2-31 -CD2-31 ~~ 2-31 -CD2-31P61 -CD2-31P61 CD2-31 -CD2-31PB1 -CD2-31P61 CD2-40 - CD2-40 - CD2-40 CD2-40 - CD2-40 - CD2-40 CD2-40 -CD2-40P61 -CD2-40P61 1,345.84 .440.29 1,345.84. 415.70 1,575.00 17.909 Centre Distance Pass -Major Risk CD2-40 -CD2-40P61 -CD2-40PB1 1,361.44 440.46 1,361.44 415.64 1,600.00 17.746 Clearance Factor Pass -Major Risk CD2-43 - CD2-43 - CD2-43 1,285.49 378.10 1,285.49 353.42 1,525.00 15.320 Centre Distance Pass -Major Risk CD2-43 - CD2-43 - CD2-43 1,300.00 378.12 1,300.00 353.13 1,550.00 15.132 Clearance Factor Pass -Major Risk CD2-43 -CD2-43P61 -CD2-43PB1 1,285.49 378.10 1,285.49 353.42 1,525.00 15.320 Centre Distance Pass -Major Risk CD2-43 -CD2-43P61 -CD2-43P61 1,300.00 378.12 1,300.00 353.13 1,550.00 15.132 Clearance Factor Pass -Major Risk CD2-43 -Prelim: CD2-43A -CD2-43Awp02 1,285.49 378.10 1,285.49 353.40 1,525.00 15.307 Centre Distance Pass -Major Risk CD2-43 -Prelim: CD2-43A -CD2-43Awp02 1,300.00 378.12 1,300.00 353.11 1,550.00 15.119 Clearance Factor Pass -Major Risk CD2-463 -CD2-463 -CD2-463 198.87 199.68 198.87 195.46 200.00 47.254 Centre Distance Pass -Major Risk CD2-463 -CD2-463 -CD2-463 422.29 200.91 422.29 191.82 425.00 22.111 Clearance Factor Pass -Major Risk CD2-464 -CD2-464 -.CD2-464 36.30 180.15 36.30 179.14 36.48 178.200 Centre Distance Pass -Major Risk w 12 December, 2008 - 9:50 Page 2 of 6 COMPASS ~AL~1 ~JF~Tt~I\I ConocoPhillips(Alaska) Inc. -WNS Western North Slope Anticollision Report for Plan: CD2-73 -CD2-73wp04 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD2 Alpine Pad -Plan: CD2-73 -Plan: CD2-73 -CD2-73wp04 Scan Range: 0.00 to 23,115.80 ft. Measured Depth. Scan Radius is 2,507.95 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum Measured Ellipse Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name -Design (ft) (ft) (ft) (ft) ft CD2-464 -CD2-464 -CD2-464 423.17 181.48 423.17 172.68 425.00 20.606 Clearance Factor Pass -Major Risk CD2-465 -CD2-465 -CD2-465 1,028.99 147.59 1,028.99 128.27 1,050.00 7.640 Centre Distance Pass -Major Risk CD2-465 -CD2-465 -CD2-465 1,051.57 147.68 1,051.57 127.89 1,075.00 7.465 Clearance Factor Pass -Major Risk CD2-466 -CD2-466 -CD2-466 348.88 139.77 348.88 132.69 350.00 19.723 Centre Distance Pass -Major Risk CD2-466 -CD2-466 -CD2-466 398.52 140.06 398.52 132.16 400.00 17.712 Clearance Factor Pass -Major Risk CD2-467 -CD2-467 -CD2-467 1,176.59 .112.85 1,176.59 91.73 1,225.00 5.342 Clearance Factor Pass -Major Risk CD2-467 -CD2-467PB1 -CD2-467P61 1,176.59 112.85 1,176.59 91.73 1,225.00 5.342 Clearance Factor Pass -Major Risk CD2-469 -CD2-469 -CD2-469 593.30 77.32 593.30 66.12 600.00 6.904 Centre Distance Pass -Major Risk CD2-469 -CD2-469 -CD2-469 641.66 77.80 641.66 65.73 650.00 6.442 Clearance Factor Pass -Major Risk CD2-470 -CD2-470 -CD2-470 766.55 55.36 766.55 40.43 775.00 3.707 Centre Distance Pass -Major Risk ^-~-~ ./~.J CD2-470 -CD2-470 -CD2-470 814.99 55.59 814.99 39.84 825.00 3.529 Clearance Factor Pass -Major Risk ..-~.... CD2-54 -CD2-54 -CD2-54 1,144.27 341.36 1,144.27 318.55 1,325.00 14.961 Centre Distance Pass -Major Risk CD2-54 -CD2-54 -CD2-54 1,160.85 341.47 1,160.85 318.30 1,350.00 14.740 Clearance Factor Pass -Major Risk _ CD2-54 -CD2-54L1 -CD2-54L1 144.27 1 341.36 1,144.27 318.55 1,325.00 14.961 Centre Distance Pass -Major Risk CD2-54 -CD2-54L1 -CD2-54L1 , 1,160.85 341.47 1,160.85 318.31 1,350.00 14.740 Clearance Factor Pass -Major Risk CD2-59 -CD2-59 -CD2-59 1,385.93 335.49 1,385.93 309.41 1,650.00 12.868 Centre Distance Pass -Major Risk CD2-59 -CD2-59 -CD2-59 17,162.25 521.41 17,162.25 67.55 20.027.00 1.149 Clearance Factor Pass -Major Risk CD2-59 -CD2-59PB1 -CD2-59PB1 1,385.93 335.49 1,385.93 309.41 1,650.00 12.868 Centre Distance Pass -Major Risk CD2-59 -CD2-59P61 -CD2-59PB1 1,400.00 335.58 1,400.00 309.18 1,675.00 12.711 Clearance Factor Pass -Major Risk CD2-72 -CD2-72 -CD2-72 47.57 20.07 47.57 18.87 50.00 16.788 Centre Distance Pass -Major Risk CD2-72 -CD2-72 -CD2-72 447.17 22.45 447.17 13.15 450.00 2.414 Clearance Factor Pass -Major Risk CD2-75 -CD2-75 -CD2-75 274.59 39.63 274.59 34.53 275.00 7.768 Centre Distance Pass -Major Risk CD2-75 -CD2-75 -CD2-75 324.58 39.90 324.58 33.86 325.00 6.611 Clearance Factor Pass -Major Risk Plan: CD2~61 -Plan: CD2-461 -CD2-461wp05 299.90 240.02 299.90 233.66 300.00 37.738 Centre Distance Pass -Major Risk Plan: CD2-461 -Plan: CD2-461 -CD2-461wp05 399.88 240.98 399.88 232.45 400.00 28.248 Clearance Factor Pass -Major Risk Plan: CD2-462 -Plan: CD2-462 -CD2-462wp05 249.70 219.95 249.70 214.68 250.00 41.723 Centre Distance Pass -Major Risk Plan: CD2-462 -Plan: CD2-462 -CD2-462wp05 349.67 221.11 349.67 213.67 350.00 29.708 Clearance Factor Pass -Major Risk Plan: CD2-471 -Plan: CD2-471 -CD2-471wp04 424.63 39.44 424.63 30.37 425.00 4.348 Centre Distance Pass -Major Risk Pian: CD21}71 -Plan: CD2-471 -CD2-471wp04 473.97 40.12 473.97 29.97 475.00 3.953 Clearance Factor Pass -Major Risk Plan: CD2-74 -Plan: CD2-74 -CD2-74wp03 400.00 20.02 400.00 11.49 400.00 2.347 Centre Distance Pass -Major Risk 12 December, 2008 - 9:50 Page 3 of 6 COMPASS ConocoPhillips(Alaska) Inc. -WNS ~~ V T~~ Western North Slope Anticollision Report for Plan: CD2-73 -CD2-73wp04 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD2 Alpine Pad -Plan: CD2-73 -Plan: CD2-73 -CD2-73wp04 Scan Range: 0.00 to 23,115.80 ft. Measured Depth. Scan Radius is 2,507.95 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Weilbore Name -Design (ft) (ft) (ft) (ft) ft Plan: CD2-74 -Plan: CD2-74 -CD2-74wp03 651.66 22.41 651.66 8.43 650.00 1.603 Clearance Factor Pass -Major Risk Rig: CD2-468 -Rig: CD2-468 -CD2-468wp05 1,239.39 45.52 1,239.39 20.37 1,275.00 1.810 Centre Distance Pass -Major Risk • Rig: CD2-468 -Rig: CD2-468 -CD2-468wp05 1,263.44 45.88 1,263.44 20.16 1,300.00 1.784 Clearance Factor Pass -Major Risk Rig: CD2-468 -Rig: CD2-468 -Rig: CD2-468 1,313.44 37.40 1,313.44 13.21 1,350.00 1.546 Centre Distance Pass -Major Risk Rig: CD2-468 -Rig: CD2-468 -Rig: CD2-468 1,337.80 37.81 1,337.80 12.92 1,375.00 1.519 Clearance Factor Pass -Major Risk CD4 Nanuq Pad Kuparuk 2N Pad From To SurveylPian Survey Tool (ft) (ft) 36.30 1,000.00 CD2-73wp04 CB-GYRO-SS 1,000.00 23,115.80 CD2-73wp04 MWD+IFR-AK-CAZ-SC Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor =Distance Between Profiles / (Distance Between Profiles -Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 12 December, 2008 - 9:50 Page 4 of 6 COMPASS `/ Project: Western North Slope ConocoPhillips Site: CD2AIpinePad CD2-73wp04 Well: Plan: CD2-73 Wellbore: CD2-73wp114D2-73 Quarter Mile View 12500 .-. _10000 7500 0 z 5000 0 2500 Opadw: CuaeaPh~p(Ahgcd he. •VMS GpCwraibn: -099 Jab NO: NN/A aeAt NbtlanNalh Sbps Mo~dkDatid bn: 3119 AR NO: NN/A Wdc CO3J]Mq/4 DSx 8069 APINr. NN/A RIR: NN/A OagNg ur 100 ft SYbam MD)Ratrenu: Nlam 3natmN Eurbce loedbn OrlQlnal VS Plane: 334.00 Pawl w.^ PIm:CD3J] 181136398 it VIEW VS IMane: 334.00 RKB HNQN: 81.90 R V: 89)J903.18 H Unp SY#an: APibamdlF94 Eadbn(VS)R9M enu: 4Ak '.~..i e ~q~ .rw^""" Comments: t D N O t m D) 2 E 0 n Carbo Preuew POOL: CD2-73wp04 Plan: 17748' to 23115.8' MD CD2-59: 15556' to 20027' MD CD2-72: 16917' to 21089' MD CD2-75: 15865' to 23539' MD CD2-31: 13694' to 18131' MD n Vle~ ~ ~ 8 a Q ~ e o Q e Q a e ~ 0 ^+ Page 1 of 1 (CD2-73wp04 TodboxJds) 5985700 5984700 5983700 5982700 5981700 980700 979700 978700 977700 976700 975700 12/12/2008 11:12 AM • Vertical Section long "slew VS Plane" Closest in POOL ....r+ ~. 1 Closest Approach: Reference Well: CD2-73wp04 Plan Offset Well: CD2-59 Coords. - words. - ASP ASP 3-D ctrctr Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Distance. Depth Angle Azi. TVD E(+)/W(- (334) ommants Depth Angle Azi. TVD E(+)/W(- (334j mments in Distance (845.05 ft) in Distance (845.05 ft) in POOL (17748 - in POOL (17748 - 23115.8 MO) to 23115.8 MD) to CD2-59 (15556 - CD2-73wp04 Plan $45. t)5 17748.95 86 305 7260.413 5978933 1496742 10697.7 20027 MD) 20027 89.57 334.41 7294.234 5978173 1497111 9855.345 (15556 -20027 MD) Closest Approach: Reference Well: CD2-73wp04 Plan Offset Weli: CD2-72 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. InG. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Distance. -~ Depth Angle Azi. TVD E(+)/W(- (334y menu Depth Angle Azi. TVD E(+)/W(- (334j manfs m Distance (1900.4 ft) m Distance (1900.4 ft in POOL (17748 - in POOL (17748 - 23115.8 MD) to 23115.8 MD) to CD2-72 (16917 - CD2-73wp04 Plan 19{)0.4 19975 90.28 334.49 7256.06 5980800 1495596 12874.35 21089 MD) 18619.5 89.02 334.55 7212.7 5981585 1497326 12860.97 (16917 - 21089 MD) Closest Approach: Reference Well: CD2-73wp04 Plan ''Offsta Well: CD2-31 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Distance. Depth Angle Azi. TVD E(+)/W(. (334j ommants Depth Angle Azi. TVD E(+)/W(- (334) meets u~ Distance.. (2247.92 m Distance (2247.92 ft) in POOL (17748 ft) in POOL (17748 - 23115.8 MD) to. - 23115.8 MD) to CD2-31 (13694 - CD2-73wp04 Plan 2247.9! 17748.95 86 305 7260.413 5978933 1496742 10697.7 18131 MD) 18131 90.52 330.79 7258.608 5978712 1498979 9553.685 (13694 - 18131 MD) Closes t Approach: Reference Well: CD2-73wp04 Plan Offset We{1: Ct~2-75 Coords. - Coords. - ASP ASP 3-D eer-ctr -. Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Distance. Depth Angle Azi. TVD E(+)/W(- (334) meets Depth Angle Azi. TVD E(+)/W(- (334) meets m Distance (2400.04 in Distance (2400.04 ft) in POOL (17748 tt) in POOL"(17748 -23115.8MD)fo -23115.8MD)to CD2-75 (15865 - ~ CD2-73wplkl Plan 240Q 17748.95 86 305 7260.413 5978933 1496742 10697.7 23539 MD) 23539 91.2 329 7303.097 5976902 1495464 9398.123 (15865- 23539 MD) CD2-73wpU4 PoolSummary.xls 12/1212008 11:21 AM • 1 4/18/07 CZ DB C. A. ISSUED PER K07041ACS 2 4/21/08 CZ GD C. A. UPDATED PER K080010ACS CD2 ~' S K ~~ CD2 ACCESS ROAD NPN PIN LOCATION OF THIS SURVEY "' ECT 2 DRILL ITE CD- T1 1 ~,_ N I p 2 (~ D ALPINE SATELLITE DEVELOPMENT VICINITY MAP NOT TO SCALE t¢ ~ p~w. F t ,i< ~ t ? ASPC ~ _ ~~ o N ? ~ ~~ t ~ i PLANT i i _ -a- g N = ` ~~ ~ ~~t ~, ° ~ ~~ l~~ m.-~ t a 06"03'45' ' c- _ t N -~-a }i O LC11F C D - ~ ~" ~ -~ -~- ' t U ® } ~ PAD '~`~~" - ~ ®~ ? :f ;; ?. i Y ,i O ~ ~ i~ t~..~r--~' -- ~ 8 i cZii '4 ~ ? ~ ~, t U1 Y ti! ~ ri ~- a ?? ~ ~ ~ t zt ~ ~ ~ ? ? t ~ i ~t ? t ~ ~"Il ?y~ i i ? ~7:'~'..6i A ~ QANNIK ~ "~~~--- CONDUCTORS ~ ~ ~---~ '' cnP~~ ~ -0 l i ~~ 4.N -- ~~ ~ 'F~ ~ ~i • ^~p ~ ~ <Mp Np ~ ~f1 ~ w m rr r^^rO d ~~p ~p'~ Npp NpN NNoo N Np NpQ aV N Np Np ~ ~ U O V U U~ U U U U fJUUUUUUU U LEGEND: KU U KP I K O PROPOSED CONDUCTOR j 7 • EXISTING CONDUCTOR _~~ L~CMF~ 799 E51rtAva ~ AMmp. Al~/a W W3 ~ (BO1)Y71189D apiire orc x i9otl6to-ot~ Alpine Survey Office ~.~ ALPINE MODULE:CD20 UNIT: QNK C~noc~Philli S ALPINE PROJECT QANNIK WELL CONDUCTORS Alaska, Inc. AS-BUILT LOCATIONS CADD FILE N0. DRAWING N0: PART: REV: 07-02-18-1 4/1 /07 - __ , ~~,-,(~q20-139 _1 of 3 2 • 1 ~ 4/18/07 ~ CZ ~ DB ~ C.A. ~ ISSUED PER K07041ACS 12 ~ 4/21/08 I CZ ~ GD I C.A. ~ UPDATED PER K080010ACS ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC.2, T 1 1 N, R 4 E, U.M. WELL 'Y' 'X' LAT.(N) LONG.(W) SEFSLNE OF L GND PAIDT CD2-461 5 973 927.48 1 511 501.61 70' 20 14.465 151' 02 45.814 3099 1765 8.3 15.7 CD2-462 5 973 925.28 1 511 481.66 70' 20 14.440 151' 02 46.395 3096 1785 8.3 15.7 CD2-463 5 973 923.32 1 511 461.85 70' 20 14.417 151' 02 46.973 3094 1805 8.3 15.7 CD2-464 5 973 921.12 1 511 442.08 70' 20 14.392 151' 02 47.549' 3091 1825 8.3 15.7 C D2-465 5 973 919.18 1 511 422.01 70' 20 14.370 151' 02 48.134'..... . 3089 1845 7.8 15.7 C D2-466 5 973 916.76 1 511 402.40 70' 20 14.343 151' 02 48.706 3086 1864 7.8 15.7 C D2-467 5 973 915.01 1 511 382.20 70' 20 14.322 151' 02 49.295 3084 1884 7.9 15.7 C D2-468 5 973 912.62 1 511 362.41 70' 20 14.295 151' 02 49.872 3081 1904 7.9 15.6 C D2-469 5 973 910.54 1 511 342.61 70' 20 14.271 151' 02 50.449" 3079 1924 8.0 15.6 C D2-470 5 973 908.62 1 511 322.72 70' 20 14.249 151' 02 51.029 3077 1944 8.0 15.6 C D2-471 5 973 906.37 1 511 302.77 70' 20 14.224 151' 02 51.610 3074 1964' 8.1 15.6 C D2-72 5 973 904.22 1 511 282.90 70' 20 14.199 151' 02 52.189 3072 1984 8.1 15.6 C D2-74 5 973 899.86 1 511 243.06 70' 20 14.150 151' 02 53.351 3067 2023 8.3 15.6 C D2-75 5 973 897.83 1 511 223.26 70' 20 14.126 151' 02 53.928 3064 2043 8.4 15.6 C D2-x76 5 793 895.84 1 511 203.39 70' 20 14.103 151' 02 54.507 3062 2063' 8.4 15.6 C D2-x77 5 973 893.62 1 511 183.28 70' 20 14.078 151' 02 55.094 3059 2083 8.4 15.6 C D2-x78 5 973 891.66 1 511 163.81 70' 20 14.055 151' 02 55.661 3057 2103 8.4 15.6 NOTES: 1. COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B.P.M.S.L.) KUUKPIK I.~CMF~ fi EllrA~. NmsM.l~la i®~ l®19dAp0 •b%~. ao-. lsoalsrwta9 Alpine Survey Office ~~ ALPINE MODULE: CD20 UNIT: QNK C~noc~Phillips ALPINE PROJECT QANNIK WELL CONDUCTORS Alaska, Inc. AS-BUILT LOCATIONS CADD FILE N0. DRAWING N0: PART: REV: 07-02-18-1 4/2/07 ~ f'1 1 ~~~Gp-139 _ 2 of 3 2 • REV DATE BY CK APP DESCRIPTION REV DATE BY CK A?P DESCRIPTION 1 4/18/07 CZ DB C. A. ISSUED PER K07041ACS 2 4/21/08 CZ GD C. A. UPDATED PER KOSOOtOACS NOTES 1. ALL COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. ORIGINAL GROUND ELEVATIONS WERE DERIVED FROM THE AVERAGE ELEVATION ALONG THE TOE OF THE QANNIK GRAVEL PAD. 3. BASIS OF COORDINATES: ALPINE TO CD-5 ROAD MONUMENTS PER SURVEY BY KUUKPIK/LCMF, APRIL 2007. 4. DATES OF AS-BUILT SURVEYS: WELL CONDUCTORS. CD2-461, CD2-462, CD2-463, CD2-464, 3/30/07, FB 2007-08 PGS. 2-3; CD2-465, CD2-466, CD2-467, CD2-468, CD2-469, CD2-470, CD2-471 &CD2-72, 4/16/07, LCMF2007-a9, PGS. 22-24; CD2-73, CD2-74, CD2-75, CD2-x76, CD2-x77 &CD2-x78, 4/20/08, FB 2008-8, PGS 72-75. SURVEYOR'S CERTIFICATE ~~~~~~~~~,, I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED , . •~F••A~gS~ ~~ BRUAILT I REP ESDENTSRA SIURVEY MADE TBYEMEFOR UNDER MY DIRIECT ~~ P~~ S • - ~ A ~ ~'~ '''• •••' 9 ~ 1~ SUPERVISION, THAT THE MONUMENTS SHOWN HEREON ACTUALLY EXIST ~ • •. AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE S DESCRIBED =• , = *: ,k~~ A CORRECT ~° . ~ , /.....s. 49th .........................:.... ~ LS 5077 - DATE: REGISTRATION N0. ~. ~~„~ ::• Donald G. Bruce :~ o ~ ~, i ~ s~%, No. LS-5077 ~:' ~~`` ~ • • ~~ ••• •••' SJ: KU U KP I K ~~•FO pRO~...........••• PLO .• 138 E8trtA ~Anda~.g.,Al•W888309~(8W)93-1830 Plphe 08re (80)7 B]Oi~39 Alpine Survey Office y/ ALPINE MODULE: CD20 UNIT: CD C~noc~Philli s ALPINE PROJECT p QANNIK WELL CONDUCTORS Alaska, Inc. AS-BUILT LOCATIONS CADD FILE N0. 07-02-18-1 4 2 07 DRAWING N0: 139 PART: 3 OF 3 REV: 2 Page 1 of 2 Maunder, Thomas E (DOA) From: Galiunas, Elizabeth C [Elizabeth.C.Galiunas@conocophillips.com] Sent: Tuesday, December 16, 2008 2:04 PM To: Maunder, Thomas E (DOA} Subject: RE: CD2-73 Definitely. I will bring them over today. Liz Galiunas Alpine Drilling Engineer ConocoPhillips Alaska Office: 907-265-6247 Cell: 907-903-1200 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, December 16, 2008 2:02 PM To: Galiunas, Elizabeth C Subject: RE: CD2-73 Liz, Would you and Sharon please prepare replacement 401 sheets? Only new 401 sheets are needed. I will let Chas know that they are coming. Tom From: Galiunas, Elizabeth C [mailto:Elizabeth.C.Galiunas@conocophillips.com] Sent: Tuesday, December 16, 2008 1:57 PM To: Maunder, Thomas E (DOA) Subject: RE: CD2-73 Tom, It appears our links were not working on the 10-401. The depths are incorrect and should read as follows. I apologize for this error. I have corrected our template so this does not happen again. 18. Casing Program etting Depth uantity of Cement size pecifications op Bottom . f. or sacks Hole asing fight rade oupling ength D D D inGuding stage data) 4" 16" 2.5# H-40 elded 7 7 7 114 114' re-installed 13.5" 10-3/4" 5.5# L-80 BTCM 663 7 7 3700 400 43 sx ASL3, 270 sx 1 9.875" 7-5/8" 9.7# L-80 BTCM 17711 7 7 17748 312 5 sx 15.8 cl G, 270 IC2 .75" .5" 12.6# L-80 IBT-M 16468 2 2 16500 963 bg -Liz Liz Galiunas Alpine Drilling Engineer ConocoPhillips Alaska Office: 907-265-6247 Cell: 907-903-1200 izi16i2oos Page 2 of 2 ~ ~ From: Maunder, Thomas E (DOA) [mailtoaom.maunder@alaska.gov] Sent: Tuesday, December 16, 2008 1:48 PM To: Galiunas, Elizabeth C Subject: CD2-73 Liz, I am starting to review this permit application. The depths on the wellbore drawing do not agree with the depths on the 401. Could you clarify please? Thanks in advance. Tom Maunder, PE AOGCC 12116/2008 TRANSMITTAL /L~ETT(ER CHECKLIST 2 WELL NAME ~/~l/~ ~~ ~ ~ ~"~ PTD# GAO ~ ~ ~C.O Develo went 'V Service P Non-Conventional Well FIELD: ~o~U~ ~~~ ~~ Exploratory Stratigraphic Test POOL: ~l ck,.e' `-'` / ~ / Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. , API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu h tar et zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 / 11 /2008 WELL PERMIT C HECKLIST Field & Pool COLVILLE RIVER, ALPINE OiL-120100 Well Name: ~OLVILLE RIV UNIT CD2-73 _Program SER Well bore seg PTD#:2081960 Co mpany CONOCOPHILLIPS ALASKA INC Initial ClasslType S ER 1 PEND GeoArea 890 Unit 50360 On1Off Shore On Annular Disposal Administration 1 Permit-feeaitaghed ----- ----- - - -- - -- - --- -- NA- - Yes - -- ------ -- -- --- --- --- - -- -- -- ------ -- 3$Q075; tell bore passes thruADL 3$7207 end 387212a top of prgd - . - _ - _ _ _ - - _ _ _ Serfage Igcatign in AAL 2 Lease number epprgpnate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - _ - - _ - _ - - - - _ _ _ 3 tlniquewellnameendn4mbet------------------------- --- ---- Yes--- ----interval_andTD inASRC-PJPRA02______.________---__------------------- ----- 4 ___---------------------------- ---- definedpggl e )Nell located in Yes_-_ ____OOLVIL4E-RIVER,ALPINE_OIL-120100,ggve[nedby CO443A.-________-___-_____._____-- 5 _ _ - Well located proper distance from drilling unit_boundery_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - _ _ - - _ CO 443A, Rule 3, Development wells may-not be completed within 500 lineal feet ofenoiher AOP deveiopment_ _ 6 Wflll located proper distance fto_m other wells_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ - _ - weil_not closer than 500_feei from the exterior boundary gt_the affegted area. _ _ - - - - _ - - _ - _ - - _ - _ _ - - _ 7 Suftigientegreageayailebleindrillinggnif.__---________________________ Yes___ -___Conformsto_thespecingrequirementsgfl2ule_3,CO443A____-______--___-__--__--__ -__-. 8 Ifdeyiated,isweliboreplat_included-- -- -- - - - - -- - Yes-- -- -- -- -- - - -- -- --- -----~ -- -- --- -- -- --- -- 9 Qperatorgnlyaffegtedparty------------------------- - - - --- Yes - ---- -- -- -- - ----- - -- - -- - --- - ---- -- 10 Operator has_appropriatebondinforce -- --- - - -- -- -- - --- Yes-- -- -- - - - -- -- ---- ------ -- -- - - --- ----- 11 Permit can betssued without gonservatign grder- - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 12 Petmikcanbeissuedwithoutadminist[ativ_e_approval------------------------ Yes--- ----------.------------------ -- -- -- ----- - - -- -- -- 13 Can pertnit-bs;3pprgvedbefgrQ 15•daY-visit--- -- - --- ---- - -- -- Yes-- -- -- -- --- -- -- ------ --------- - - -- - - --- -- SFD 12!1512008 14 !Nell located within area and_strata authgrized by Injeciion Older fl (put_IO# in-comments).(Fgr_ Yes _ _ _ _ _ _ _ Injection ggverned by Area Injection Order No,188_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 15 All wells-vtithinll4_mileareeofreyiewidentified(Fotserviceweligni .- y)- - - - - - Yes___ -___CRlJCD2.59_______________________________-__.-__--_---__--______----- 16 Pre-Reduced injec~9r duration of pre ~toduoti4n less than 3 mgnihs_ (Forssrvice well only) _ _ No- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 17 Nonconven, gas_cgofgmts to AS31,05,OS0(G1.A),tL2.A-D) - - - - - - - - - - KA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ ----- -- 18 Conductotstring_provided -- ---- --- - ----- -- ------ Yes -- -- -- - --- --- -- ------ - - - - -- -- - -- Engineering 19 Surface_casingprgtaotsail_kngwnU$DWs------------------------------ NA---- ---No aquifers,AIQ1$A,Conclusion3,--------------------------------------- - - 20 CMT_voladequate_tgcitculate_oncgnductgr&surf.csg_-_----------------- -- Yes--- -------------------------- - -- ------- - --- - --- -- --_. -- 21 CMT-vol adequate_tg ii8-in long string to_sgrf gs9 - - - - - - - - N0 - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 22 CMT_willrAyerahknown_p_roduGtiy@hori~gns----------------------------- N°--- ----Open_holecgmpletionplanned,-------------------------------------- -- - - -- 23 Casing designs adequatefotC,_T,B_Sipe[mafrost------------------------ Yes-- Yes -------------------------- - -- -- --- -- --- - ---- Rig equipped with steel pits. iJa reserve pit planned.- All waste_tg approved annuli gr_dispgsal well(s).- _ _ - _ _ _ 24 Adequate tankage_or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ - _ _ 25 2 tOr403 for abendgnment been approved - - - - - - - - - - - - - - - - - - - - - re~lrill,bas If a ~- - - - - - - - - - - - - - - - - - - - - 26 - _ AdBquate wellbore separationpropgsed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ Proximity anelysiS performed, Ttayeling cylinder path calculated, Gyros likely-in serfage hole. _ - _ _ - _ _ _ 27 If diverier required, does it meet rQ9ulatigns_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ - - _ _ _ - Diverter waiver [equesied, Ng shallgw gas_ issues in CRU, Apprgval regommended. - _ _ - _ _ - _ _ _ - . _ _ - - a 26 prggram Schematic,& equip list adaquate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Driping fluid YeS _ - - _ _ - _ Maximum expected reservoirpress4re $.7 EMW. _MW_planned.up 1410.5 ppg. _ _ - _ _ - _ - _ _ - _ _ _ _ - _ _ _ _ te Appr D TEM 12!1612008 29 30 - BOPEs,.do they meetre9ulati9n _ - - - - - ~ - - - - - - - - - - (put prig in cgmmsnts)- - - - - - - - - - - - - - - - - prass rating appropriate; test to BOPE -Yes - - -Yes _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ _ _ _ MASP calculated at 2596 psi, 3500.p iSOP testplanned. _ _ . _ _ _ _ - - _ - - _ - - - _ - - _ - _ - - _ - - - _ 31 Chgke_manifgld comRlies wIAPI_RP-53 (May 84)- - - - - - - - - - - - - -YeS - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 32 V#lork will gccu[ without operation shutdown_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ - _ _ _ A SD is possible ata-casing point if the_i4e_rged_is gompleted_early. _ _ - - _ _ - - _ _ - - _ _ - . _ _ . _ _ _ _ _ _ _ 33 - IspresenceofH2S9asprobable----------------------------------- - No--- --___H2S nottepgdedinCRU._Rigequippedwithsensorsand_alarms.------------------------- -- 34 Mechanical condition of wells within AQR verified (Fg[service well gnly) - _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ Ng penetrations intg Alpine within 114 milQ gf CI)2.73_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ er material nd scaven l r s l t 35 Pe[mit can be issued w!o hydrogen sulfide measu[es _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ - _ _ _ g m a sensors, a iona a _ - _ Per Dulling Hazards Summary the rig will be equipped with opera Geology 36 Data_presenied gn potential gverpressure zgnes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _YeS _ _ _ _ - _ Expected resenteirpressure is 8.7-ppg BMW; will be drilled with $.$ -10.5 ppgmud, _ - _ - _ - _ - _ _ - _ . _ Appr Date 37 Se~smic_analysi& of shaligw gas_~ones- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Nfl _ _ - _ _ ..Norte expected based on numerous weld drdled_frorn GD2-Pad- _ _ - _ - - _ _ - _ _ - - _ - - - _ - - - - - - - - - SFD 12115!2008 38 Seabedcgnditionsurvex_(ifoff-shore)------------------------------- -NA___ .___.____-__--___---_-_-.----------------- --- - - -- -- ----- 39 Cogtact namelphone for weekty_pr4gress repgrfs [exPloraio gnl _ ry Y1 -- -- -- - - ~- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - U u Geologic Engineering Data Public Date Commissioner: Date: Commissioner issioner i 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 efiiorl has been made to chronologically organize this category of information. Sperry-Sun Drilling Services Lis Scan utility cd2-73.tapx $Revision• 3 $ LisLib $Revision: 4 $ Fri Aug 21 11:51:40 2009 Reel Header service name .............LISTPE Date .....................09/08/21 Origin ...................STs Reel Name...... .......UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOwN Comments .................STS LIS writing Library. scientific Technical services Tape Header Service name .............LiSTPE Date .....................09/08/21 Origin ...................STS Tape Name... .. .......UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................sTS LIS writing Library. scientific Technical services Physical EOF comment Record TAPE HEADER Colville River MWD/MAD LOGS WELL NAME: CD2-73 API NUMBER: 501032059000 OPERATOR: Conoco Phillips Alaska, Inc. LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 21-AUG-09 JOB DATA MWD RUN 2 MWD RUN 4 MWD RUN 5 Job NUMBER: Mw-000637598 Mw-000637598 Mw-000637598 LOGGING ENGINEER: E. QUAM ]. BOBBITT E. QUAM OPERATOR WITNESS: D. BURLEY M. THORNTON F. HERBERT SURFACE LOCATION SECTION: 2 TOWNSHIP: 11N RANGE: 4E FNL: 2210 FSL: FEL: 2003 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: .00 DERRICK FLOOR: 53.05 GROUND LEVEL: 15.60 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 3658.0 2ND STRING 6.750 7.625 17720.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. CD2-73 SIDETRACKED FROM THE CD2-73 PB1 WELLBORE AT 3,724' MD, 2,407' TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE Page 1 add- !°~~ ~~~~~ • cd2-73.tapx PRESENTED. 5. MWD RUN 2 AND 4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), DRILLSTRING DYNAMICS SENSOR (DDSr), AT-BIT GAMMA (ABG) AND GEOPILOT ROTARY-STEERABLE BHA (GP). 6. MWD RUN 3 NO FOOTAGE DRILLED - NO DATA ARE PRESENTED. 7. ABG DATA WERE APPENDED TO DGR DATA FROM 17,683'MD - 17,715' MD AT THE BOTTOM OF RUN 4 INTERVAL. 8. MWD RUN 5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), DRILLSTRING DYNAMICS SENSOR (DDSr), G20Tap (FPWD) AND GEOPILOT ROTARY-STEERABLE BHA (G P). 9. RATE OF PENETRATION DATA FROM 17,720' MD TO 17,740' MD FROM A CLEANOUT RUN WERE APPENDED TO THE TOP OF RUN 5 INTERVAL. lO.MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. 11.MWD RUNS 1-5 REPRESENT WELL CD2-73 WITH API#: 50-103-20590-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 21,810'MD 7,328' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR SROP AND SGRC. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header service name... .....STSLIB.001 service Sub Level Name... version Number.. ........1.0.0 Date of Generation.......09/08/21 Maximum Physical Record..65535 File rype.. ...........Lo Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3634.0 21760.5 FET 3648.0 21767.5 Page 2 + M cd2-73.tapx RPD 3648.0 21767.5 RPS 3648.0 21767.5 RPM 3648.0 21767.5 RPx 3648.0 21767.5 ROP 3668.5 21810.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 3634.0 3724.0 MWD 4 3724.0 17720.0 MwD 5 17720.0 21810.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type.. .........0 Data specification Block Type .....0 Loggin Di rection ......... ... .....DOwn optical log depth units... ... .....Feet Data Reference Point ...... ... .....undefined Frame Spacing ....... .... ... .....60 .liN Max frames per record ..... ... .....undefined Absent value .............. ... .....-999 Depth Units........ .. .. ..... Datum specification Block sub -type...0 Name service order units size N sam Rep code offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 FlrSt LdSt Name Service Unit Min Mdx Mean Nsam Reading Redding 21810 DEPT FT 3634 21810 12722 36353 3634 RPD MWD OHMM 0.03 2000 12.229 36179 3648 21767.5 RPM MWD OHMM 0.07 1956.71 10.8246 36179 3648 21767.5 RPS MWD OHMM 0.77 1926.93 9.70976 36179 3648 21767.5 RPx MWD OHMM 1.16 2000 7.10554 36179 3648 21767.5 FET MWD HR 0.15 4167.54 5.81149 36179 3648 21767.5 GR MwD API 36.59 346.47 102.319 36254 3634 21760.5 ROP MWD FPH 0.37 405.28 192.042 36284 3668.5 21810 First Reading For Entire File..........3634 Last Reading For Entire File...........21810 File Trailer Service name... ......STSLIB.001 Service SUb Level.Name... version Number.. ........1.0.0 Date of Generation.......09/08/21 Maximum Physical Record..65535 File Type ................LO Next Fipe Name...........STSLI6.002 Physical EOF File Header Service name... ......STSLI6.002 Service Sub Level Name... Page 3 version Number.. ........1.0.0 Date of Generation.......09/08/21 Maximum Physical Record..65535 File Type.. .........LO Previous File Name.......sT5LI6.001 cd2-73.tapx Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 3634.0 3724.0 SFXE 3648.0 3724.0 SEXP 3648.0 3724.0 SESP 3648.0 3724.0 SEMP 3648.0 3724.0 SEDP 3648.0 3724.0 SROP 3668.5 3724.0 LOG HEADER DATA DATE LOGGED: 05-]UL-09 SOFTWARE SURFACE SOFTWARE VERSION: InSite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 3724.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 67.4 MAXIMUM ANGLE: 85.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dudl Gamma Ray 132482 EWR4 EWR-Phase 4 105242 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 3658.0 BOREHOLE CONDITIONS MUD TYPE: Fresh water Gel MUD DENSITY (LB/G): 9.60 MUD VISCOSITY (S): 39.0 MUD PH: 9.7 MUD CHLORIDES (PPM): 550 FLUID LOSS (C3): 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.400 90.0 MUD AT MAX CIRCULATING TERMPERATURE: .837 155.0 MUD FILTRATE AT MT: 1.300 75.0 MUD CAKE AT MT: 2.100 75.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type.. ........0 Data specification Block Type.....0 Loping DireCtiOn .................DOWn Optical log depth units...........Feet Data Reference Point ..............undefined Page 4 Frame Spacing ....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units........ .. .. ..... Datum specification Block sub-type...0 cd2-73.tapx Name service order units size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RP5 MwD020 OHMM 4 1 68 12 4 RPX MwD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 RoP MwD020 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3634 3724 3679 181 3634 3724 RPD MWD020 OHMM 3.06 2000 153.321 153 3648 3724 RPM MWD020 OHMM 3.47 1956.71 49.6259 153 3648 3724 RPS MWDO20 OHMM 2.95 1926.93 38.8482 153 3648 3724 RPX MWD020 OHMM 1.73 2000 37.8331 153 3648 3724 FET MwD020 HR 0.18 4167.54 1169.41 153 3648 3724 GR MWD020 API 61.49 160.41 117.672 181 3634 3724 ROP MWD020 FPH 0.37 216.94 134.946 112 3668.5 3724 First Reading For Entire File..........3634 Last Reading For Entire File...........3724 File Trailer service name... .....sT5LI6.002 service sub Level Name... version Number.. ........1.0.0 Date of Generation.......09/08/21 Maximum Physical Record..65535 File TyPe ................LO Next File Name...........5TSL26.003 Physical EOF File Header Service name... .......STSLIB.003 Service Sub Level~Name... version Number.. ........1.0.0 Date of Generation.......09/08/21 Maximum Physical Record..65535 File Type.. ...........LO Previous File Name.......ST5LI6.002 comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SFXE 3724.5 17666.0 SESP 3724.5 17666.0 SGRC 3724.5 17715.0 SEXP 3724.5 17666.0 SEMP 3724.5 17666.0 SEDP 3724.5 17666.0 SROP 3724.5 17720.0 LOG HEADER DATA DATE LOGGED: 30-JUL-09 SOFTWARE SURFACE SOFTWARE VERSION: Insite Page 5 cd2-73.tapx DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 17720.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 65.4 MAXIMUM ANGLE: 84.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 132482 EWR4 EWR-Phase 4 105242 S BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 3658.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 10.00 MUD VISCOSITY (S): 36.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 400 FLUID LOSS (C3): 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.500 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .680 162.5 MUD FILTRATE AT MT: 1.200 70.0 MUD CAKE AT MT: 2.200 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type.. .......0 .. Data specification Block Type.....0 Coggin Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing ....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units ....... .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MwD040 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3724.5 17720 10722.3 27992 3724.5 17720 RPD MwD040 OHMM 0.03 1776.64 7.04969 27884 3724.5 17666 RPM MwD040 oHMM 0.07 751.64 6.58306 27884 3724.5 17666 RPS MWD040 OHMM 0.77 21.06 6.15812 27884 3724.5 17666 RPX MWD040 OHMM 1.16 20.08 5.84369 27884 3724.5 17666 FET MwD040 HR 0.15 7.25 0.46836 27884 3724.5 17666 GR MwD040 API 49.81 346.47 115.063 27982 3724.5 17715 ROP MWD040 FPH 1.27 405.28 222.762 27992 3724.5 17720 Page 6 cd2-73.tapx First Reading For Entire File..........3724.5 Last Reading For Entire File...........17720 File Trailer Service name... .....STSLI6.003 service Sub Level Name... version Number.. ........1.0.0 Date of Generation.......09/08/21 Maximum Physical Record..65535 File rype ................LO Next File Name...........ST5LI6.004 Physical EOF File Header Service name... .......STSLI6.004 SerVlCe SUb L2Vel.Name... version Number.. ........1.0.0 Date of Generation.......09/08/21 Maximum Physical Record..65535 File Type.. .........LO Previous File Name.......STSLi6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SEMP 17697.0 21767.5 SEXP 17697.0 21767.5 SEDP 17697.0 21767.5 SFXE 17697.0 21767.5 SESP 17697.0 21767.5 SGRC 17715.5 21760.5 SROP 17720.5 21810.0 S LOG HEADER DATA DATE LOGGED: 11-AUG-09 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 21810.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 83.9 MAXIMUM ANGLE: 93.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 268169 EWR4 Slim EWR-Phase 4 148579 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 17705.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.55 MUD VISCOSITY (S): 40.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 70000 FLUID LOSS (C3): 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .120 71.0 Page 7 ~ ~ cd2-73.tapx MUD AT MAX CIRCULATING TERMPERATURE: .053 168.0 MUD FILTRATE AT MT: .100 71.0 MUD CAKE AT MT: .140 71.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type.. ....... 0 Data Specification Block Type..... 0 Loggin Direction ................. DOwn optical log depth units........... Feet Data Reference Point .............. undefined Frame Spacing...... ............ 60 .lIN Max frames per record ............. undefined Absent value ...................... -999 Depth Units.. .. Datum specification Block sub~type ...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MwD050 OHMM 4 1 68 12 4 RPX MwD050 OHMM 4 1 68 16 5 FET MwD050 HR 4 1 68 20 6 GR MwD050 API 4 1 68 24 7 ROP MwD050 FPH 4 1 68 28 8 First Last Name Service Unit Min Mdx Mean Nsam Reading Reading DEPT FT 17697 21810 19753.5 8227 17697 21810 RPD MwD050 OHMM 3.36 2000 27.3152 8142 17697 21767.5 RPM MWD050 OHMM 3.65 1135.19 24.6216 8142 17697 21767.5 RPS MWD050 OHMM 2.87 845.71 21.3256 8142 17697 21767.5 RPX MWD050 OHMM 1.81 47.26 10.8496 8142 17697 21767.5 FET MWD050 HR 0.4 221.25 2.24447 8142 17697 21767.5 GR MwD050 API 36.59 111.45 57.9019 8091 17715.5 21760.5 ROP MwD050 FPH 4.46 162 87.6998 8180 17720.5 21810 First Reading For Entire File..........17697 Last Reading For Entire File...........21810 File Trailer Service name... .....STSLI6.004 service sub Level Name... version Number.. ........1.0.0 Date of Generation.......09/08/21 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLi6.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................09/08/21 Origin ...................STS Tape Name... .......UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS writing Library. Scientific Technical Services Reel Trailer Service name .............LiSTPE Page 8 cd2-73.tapx Date .....................09/08/21 Ori9in ...................5T5 Reel Ndme... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library. scientific Technical services Physical EOF Physical EOF End Of LIS File Page 9 s ~ cd2-73pbl.tapx Sperry-Sun Drilling Services LIS Scan utility $Revision• 3 $ LisLib $Revision: 4 $ wed Aug 19 10:52:45 2009 Reel Header service name .............LISTPE Date .....................09/08/19 Ori9in ...................STS Reel Name... .......UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services Tape Header Service name .............LISTPE Date .....................09/08/19 Origin ...................STS Tape Name... .......UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN comments .................STS LIS writing Library. scientific Technical services Physical EOF Comment Record TAPE HEADER Colville River MWD/MAD LOGS WELL NAME: CD2-73 PB1 API NUMBER: 501032059070 OPERATOR: COnOCOPhl11lp5 Alaska, InC. LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 19-AUG-09 JOB DATA MWD RUN 2 JOB NUMBER: Mw-000637598 LOGGING ENGINEER: E. QUAM OPERATOR WITNESS: D. BURLEY SURFACE LOCATION SECTION: 2 TOWNSHIP: 11N RANGE: 4E FNL: 2210 FSL: FEL: 2003 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: .00 DERRICK FLOOR: 53.05 GROUND LEVEL: 15.60 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 3658.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) Page 1 d©v'~c0 l~~~o cd2-73pbl.tapx UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), DRILLSTRING DYNAMICS SENSOR (DDS r), AT-BIT GAMMA (ABG) AND GEOPILOT ROTARY-STEERABLE BHA (GP). 5. ABG DATA WERE APPENDED TO DGR DATA FROM 17,797'MD - 17,826' MD AT THE BOTTOM OF RUN 2 INTERVAL. 6. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. 7. MWD RUNS 1-2 REPRESENT WELL CD2-73P61 WITH API#: 50-103-20590-70. THis WELL REACHED A TOTAL DEPTH (TD) OF 17,830'MD 7,310' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR SROP AND SGRC. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL 25 SET TO 5 FT FOR ALL CURVES. File Header Service name... .....STSLIB.001 service Sub Level~Name... version Number.. ........1.0.0 Date of Generation.......09/08/19 Maximum Physical Record..65535 File Type .. .............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curv es; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3634.0 17826.0 RPD 3648.0 17780.0 RPM 3648.0 17780.0 RP5 3648.0 17780.0 RPX 3648.0 17780.0 FET 3648.0 17780.0 ROP 3668.5 17830.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 3634.0 17830.0 REMARKS: MERGED MAIN PASS. Page 2 cd2-73pbl.tapx Data Format Specification Record Data Record Type.. ....... 0 Data specification Block Type..... 0 Loping Direction ................. DOwn optical log depth units........... Feet Data Reference Point .............. Undefined Frame Spacing ....... ............ 60 .lIN Max frames per record ............. undefined Absent value ...................... -999 Depth units........ .. .. ..... Datum specification Block sub-type ...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 First Last Name SerVl Ce Unit Min Mdx Mean Nsam Reading Reading 178 0 DEPT FT 3634 17830 10732 28393 3634 3 RPD MWD OHMM 0.05 2000 7.77895 28265 3648 17780 RPM MWD OHMM 0.14 1956.71 6.58553 28265 3648 17780 RPS MWD OHMM 1.34 1926.93 6.21814 28265 3648 17780 RPX MWD OHMM 1.34 2000 5.90768 28265 3648 17780 FET MWD HR 0.14 4167.54 6.76178 28265 3648 17780 GR MwD API 48.58 379.77 112.596 28385 3634 17826 ROP MWD FPH 0.37 619.65 226.6 28324 3668.5 17830 First Reading For Entire File..........3634 Last Reading For Entire File...........17830 File Trailer Service name... .....STSLIB.001 Service Sub Level Name... version Number.. ........1.0.0 Date of Generation.......09/08/19 Maximum Physical Record..65535 File Ty e ................Lo Next File Name...........STSLIB.002 Physical EOF File Header Service name... ......STSLI6.002 service sub Level~Name... version Number.. ........1.0.0 Date of Generation.......09/08/19 Maximum Physical Record..65535 File Type.. ...........Lo Previous File~Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 3634.0 17826.0 SEDP 3648.0 17780.0 SEMP 3648.0 17780.0 SESP 3648.0 17780.0 SEXP 3648.0 17780.0 Page 3 cd2-73pbl.tapx SFXE 3648.0 17780.0 SROP 3668.5 17830.0 LOG HEADER DATA DATE LOGGED: 05-JUL-09 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 17830.0 TOP LOG INTERVAL (FT): 3668.0 BOTTOM LOG INTERVAL (FT): 17830.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 67.4 MAXIMUM ANGLE: 85.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 132482 EWR4 EWR-Phase 4 105242 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 3658.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (5): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Fresh water Gel 9.60 39.0 9.7 550 3.0 1.400 90.0 .837 155.0 1.300 75.0 2.100 75.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type.. .......0 .. Data. specification Block Type.....0 Logyin Di rection .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing ....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units ....... .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MwD020 oHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 First Last Name SerVlCe Unit Min Mdx Mean NSdm Reading Reading 17830 DEPT FT 3634 17830 10732 28393 3634 Page 4 cd2-73pbl.tapx RPD MwD020 OHMM 0.05 2000 7.77895 28265 3648 17780 RPM MWD020 OHMM 0.14 1956.71 6.58553 28265 3648 17780 RPS MWD020 OHMM 1.34 1926.93 6.21814 28265 3648 17780 RPX MWD020 OHMM 1.34 2000 5.90768 28265 3648 17780 FET MwD020 HR 0.14 4167.54 6.76178 28265 3648 17780 GR MWD020 API 48.58 379.77 112.596 28385 3634 17826 ROP MWD020 FPH 0.37 619.65 226.6 28324 3668.5 17830 First Reading For Entire File..........3634 Last Reading For Entire File...........17830 File Trailer Service name... ......STSLI6.002 service sub Level Name... version Number.. ........1.0.0 Date of Generation.......09/08/19 Maximum Physical Record..65535 File TyPpe ................LO Next Flle Name...........STSLI6.003 Phy5lCd1 EOF Tape Trailer service name .............LiSTPE Date .....................09/08/19 Origin ...................5T5 Tape Name... .......UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN comments .................5T5 LIS writing Library. scientific Technical services Reel Trailer Service name .............LISTPE Date .....................09/08/19 Ori9in ...................STS Reel Name... .......UNKNOWN Continuation Number......01 Next Reel Name...........uNKNOwN Comment5 .................5T5 LIS writing Library. Scientific Technical Services Physical EOF PhySiCal EOF End Of LIS File Page 5
