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Home My WebLink About205-033 STATE OF ALASKA Ai:A OIL AND GAS CONSERVATION COM ION �` REPORT OF SUNDRY WELL OPE TIONS MAY 16 2818 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull TubingU U Ok^r:�' h 'off Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Chang . •.. .;klyr ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Tubing Patch H❑✓ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska,Inc. Development ❑ Exploratory ❑ 205-033 3.Address: P.O.Box 100360 Stratigraphic ❑ Service Q 6.API Number: Anchorage,AK 99510 50-103-20507-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0364471/ADL0372104/ADL0372105 CRU CD3-108 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 18915' feet Plugs measured N/A feet true vertical 6816' feet Junk measured N/A feet Effective Depth measured 18915' feet Packer measured 10037' feet true vertical 6816' feet true vertical 6695' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 70' 16" 114' 114' Surface 3037' 9-5/8" 3075' 2431' Intermediate 11040' 7" 11076' 6998' Production Liner Perforation depth Measured depth 11076'-18915' feet SCANNED JUN 1 12018 True Vertical depth 6816'-6998' feet Tubing(size,grade,measured and true vertical depth) 4-1/2" L-80 10097' 6723' Packers and SSSV(type,measured and true vertical depth) Packer Baker Premier 10037' 6695' SSSV A-1 Inj.Valve in DB-nipple 2267' 1929' Upper Patch Packer WFT Widepak 9908' 6632' Lower Patch Packer WFT Widepak 9939' 6648' 12.Stimulation or cement squeeze summary: N/A 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: N/A N/A N/A N/A N/A Subsequent to operation: N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑' Exploratory El Development Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG Q 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: 317-217 • Authorized Name: Rachel Kautz Contact Name: Travis Smith/Rachel Kautz Authorized Title: Well Integrity Supervisor Contact Email: N2549(a conocophillips.com Authorized Signature: /�/ Date: Contact Phone: 659-7126 Form 10-404 Revised 4/20171_6/6/15ReDm Submit Original Only 4.4'67 f �- ? 1ST • ConocoPh l I i ps Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 May 13, 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 Report of Sundry Well Operations for the tubing patch repair completed on CRU CD3-108 (PTD 205-033). Please contact Travis Smith or myself at 659-7126 if you have any questions. Sincerely, Rachel Kautz Well Integrity Supervisor ConocoPhillips Alaska,Inc. ! I Date Event Summary Executive Alpine well CRU CD3-108 has known TxIA communication on gas. Results of a diagnostic Summary leak detect log suggested a gas leak point exists at 9928' RKB. A tubing patch was set across that depth in an attempt to repair the gas communication. After the patch was set, an MITIA was performed and passed. A diagnostic monitor during gas injection is planned to confirm the effectiveness of the patch. 04/25/18 DRIFT TBG TO Al INJ @ VALVE @ 2266' RKB w/3.84" G-RING. PULLED Al INJ VALVE (SN: HSS-165) @ SAME. BRUSH AND FLUSHED TBG DWN TO XN NIP @ 10084' RKB w/ FULL BORE BRUSH, 3.79" G-RING. SET 3.81" CAT SV @ 10084' RKB. PULLED 1" DGLV @ 9931' RKB. READY FOR CIRC OUT 04/26/18 PULLED 3.81" CAT SV @ 10,084' RKB. SET LOWER 3.72"WFT WIDEPAK PACKER (VO RATED ) MID ELEMENT @ 9944' RKB. CMIT TBG x IA 3500 PSI AGAINST TEST TOOL IN LOWER PACKER ( PASS ) IN PROGRESS. 04/27/18 WITH CMDFRE! SET UPPER 3.72"WFT WIDEPAK PACKER (VO RATED ) PATCH ASSEMBLY( OAL = 34'/MIN ID =2.24' ) WITH MID ELEMENT @ 9913' RKB. MIT x IA 3500 PSI ( PASS ) SET MIDIFIED A-1 INJ VLV( S/N: HABS-002 ) W/EXTENSION & DUAL PACKING STACKS @ 2266' RKB. CLOSURE TEST ON SSSV**PASS**. JOB COMPLETE. 05/10/18 State Witnessed (Austin McLeod) MIT-IA Passed to 3300 psi. Initial T/I/O = 1952/1050/508. IA FL @ surface. Pressurized IA to 3300 psi w/ 1.9 bbls diesel. Starting T/I/O = 1953/3300/532. 15 min T/I/O = 1952/3260/533. (-40). 30 min T/I/O = 1952/3250/533. (-10). Passed. Bled IA to 1050 psi (bled back 2 bbls), continued to bleed IA to 810 psi. Final T/I/O = 1952/810/506. ill, I ( WNS INJ CD3-108 1.-- Conocohillips014111 Well Attributes W Edd Name Max Angle&MD TD Welbase Status incl l`) MD(MOB) Act BUo MB} Alaska,Inc. _501032050700 FIORD NECHELIK INJ 104.85 18.755.45 18915.0 ConocciftidapsComment H2S(ppm) Date Annotation End Date KB-Gra(19 Rig Release Dale ."" SSSV:MODIFIED A-1 INJ VLV Last WO: 43.78 4/112005 MD1606.5'tOd010 6 at 06 AM Last Tag vwmisasnuaclrne0 Annotation Depth(K81 End Dete Last Mod By Last Tag: N1894 Last Rev Reason Annotation End bate Last Nod By Rev Reason:Set Patch&A-1 Injection vN 4272018 ctayg 1;�ill Casing Strings hlAW.i�i2_ti- Casing Description OD f) D Ong Top(5011 Set Depth(5(B1 Set Depth(TSO(...WtiLen(I...Grade Top Thread CONDUCTOR Insulated 16 15.062 43.8 114.0 114.0 62.50 H-40 WELDED 34" Casing Description OD(it) D(m1 Top NOW) Set Depth(MB) Set Depth(TOOL..WM.en(L..Grade Top Thread SURFACE 9 5//8 8.921 37.9 3,0747 2,431.1 36.00 J-55 BTC Casing Desapton OD(in) 0 fm) Top(Td(B) Set Depth(NISI Set Depth(TVD)...Wt/Len(L..Grade Top Dread PRODUCTION 7 6276 35.6 11.075.9 6,998.2 26.00 L-80 BTCM Casing Desa9ton OD tin) DIM) Top(61(8) Set Depth(5(81 Set Depth(TVD)...Wflien(I...Grade Top Thread OPEN HOLE 6 1/8 6.125 11,075.0 18,915.0 ifTubing Strings TubInO Descnpton -string ib...D(m) Top(tKBj Sot Depth(2..Set Depth(TVD)(_.Wt Ob/tq Grade Top Connection TUBING 4 12 3.958 32.7 10.1196.7 6,722.7 12.60 L-80 181M Completion Details Top(TVD) Top nd Nominal l .-<1".�" Top MKS) Imcel fi Item Des Com El(n) CONDUCTOR InuCYC 3a'.43 S Ills 32.7 32.7 0.00 HANGER FMC TUBING HANGER 4.500 � _t g 2,266.6 1,928.6 52.37 NIPPLE CAMCO'DB'NIPPLE 3.813 10,037.3 6.695.0 61.74 PACKER BAKER PREMIER PACKER 3.875 10.084.4 6.717.0 62.40 NIPPLE CAMCO'XN'NIPPLE 3.725 10,095.31 6,722.11 62.55 WLEG (WIRELINE ENTRY GUIDE I 3.875 6694746 2.266 0A Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 44.164E 33666 Top/PM) Top Incl Top(111113) (MLR) (`) Des Corn Run Date D(n) 0 2266.6 1,928.7 52.37 INJ VALVE 3.81"MIDIFIED A-1 INJ VLV(S/N:HABS-002)W136" 4,272018 1250 EXTENSION&DUAL PACKING STACKS 9,907.5 6,631.8 6021 Upper Packer UPPER 3.72"WFT WIDEPAK PACKER VO RATED(SN:4272018 2.375 ALPCP450008/6.4'MIN ID 2.375) 9,913.8 6,635.0 60.27 Spacer pipe& 24.02'x 2.875"SPACER PIPE&ANCHOR LATCH(SN:4/270018 2.441 Anchor Latch ALPCS45001/MIN ID 2.24") 9,939.1 6,647.5 60.52 Lower Packer 3.72"WFT WIDEPAK PACKER VO RATED(SN: 4(26/2018 2,375 ALPCP450007)((6.6'OAL MIN ID 2.375")) SURFACE.37430797 a Mandrel Inserts st at on Top ITVDI Valve Latch Port Size TRO Run N Top(tKEI (hKB1 Make Model OD(m) Sere Type Type (in) (psi) Run Deb Com 1 9,931.5 6,643.8 CAMCO KB0-2 1 GAS LIFT OPEN 4252018 Patch Notes:General&Safety End Date Annotation 4/11/2005 NOTE:TREE:FMC/Unihead System wtHorizontal Tree Genii/4-1/16-5K Upper e p 507 a ® 4/112005 NOTE:TREE CAP CONNECTION:7"'OTIS 5/14/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 3/9/2017 Note:WaNerod for Water-Only Injection due to TxIA on gas Sparer ppe 8Anclw LAM. 139159 i. GAS LIFT.9.1515 Leeer Packer 9100.1 -- aaa 13 ti PROOl1CT10N,00.0-110750 • " OPEN HOLE 11.0750-101130 -• 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regqaalaska.gov AOGCC.Inspectors@alaska.gov phoebe.brooksAalaska.gov chris.wallace[a)alaska.gov OPERATOR: ConocoPhillips Alaska Inc, FIELD/UNIT/PAD: Kuparuk/CRU/CD3 Pad DATE: 05/10/18 OPERATOR REP: Miller AOGCC REP: Austin Mcleod Well CD3-108 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2050330 Type lnj W Tubing 1952 1953 1952 1952 Type Test P Packer TVD 6695 BBL Pump 1.9 IA 1050 3300 3260 3250 Interval 0 Test psi 3000 BBL Return 2.0 OA 508 532 533 533 Result P Notes: MITIA per Sundry 317-217 Well CD3-112 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2060320 Type lnj W Tubing 2000 r 2000 2002 2002 Type Test P Packer TVD 6770 BBL Pump 1.4 IA 1180 3310 3210 3200 Interval 0 Test psi 3000 BBL Return 1.5 OA 566 826 813 809 Result P Notes: MITIA per AIO 30.007 to maximum anticipated injection pressure and per Sundry 318-163 Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: I' TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test I=Initial Test P=Passe, G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) MIT CRU CD3-108 CD3-112 05-10-18.xlsx MEMORANDA • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,May 15,2018 TO: Jim Regg Supervisor G I�e1 S('zt(( 2 SUBJECT: Mechanical Integrity Tests P.I.Prl CONOCOPHILLIPS ALASKA,INC. CD3-108 FROM: Austin McLeod COLVILLE RIV FIORD CD3-108 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name COLVILLE RIV FIORD CD3-108 API Well Number 50-103-20507-00-00 Inspector Name: Austin McLeod Permit Number: 205-033-0 Inspection Date: 5/10/2018 Insp Num: mitSAM180512184336 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD3-108 Type Inj W TVD 6695 ' Tubing 1952 1953 -1 1952 - 1952- PTD 2050330 Type Test�—_-SPT Test psi i 3000 - IA 1050 3300 • 3260 - 3250 - r--..._ — --- -- ---- 533 - 533 _ BBL Pumped: 2 I OA 508 532 Interval —_ 1.9 BBL Returned:P/F IOTHER P Notes: MIT-IA.Sundry 317-217.T/IA communicaion on gas inj-water inj only A- 30,Ot)la SCANNED JUN 0 12013 Tuesday,May 15,2018 Page 1 of 1 • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Friday,April 27, 2018 11:08 AM To: Loepp,Victoria T(DOA);Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: CRU CD3-108 (PTD#205-033, Sundry#317-217) Hello— I wanted to update you on the status of Sundry 317-217 for CRU injection well CD3-108. After some logistic delays,the retrievable tubing patch is being set in the well now. Once this work is completed,our intent is to stabilize the well on water injection and perform an MITIA. Following this, (per the Sundry)we will WAG the well to gas injection service for a 30-day monitoring period to prove the integrity of the patch in gas service. If this is successful,we will file the appropriate paperwork with the AOGCC to cancel AIO 30.008. Let me know if you have any questions or disagree with the plan. Travis Smith/Rachel Kautz Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCANNED 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,February 20,2018 TO: Jim Regg P.I.Supervisor 'Pf1 i Zf Z7(I E3 SUBJECT: Mechanical Integrity Tests t CONOCOPHILLIPS ALASKA,INC. CD3-108 FROM: Lou Laubenstein COLVILLE RIV FIORD CD3-108 Petroleum Inspector Src: Inspector Reviewed Bj P.I.Supry Ji�-- NON-CONFIDENTIAL Comm Well Name COLVILLE RIV FIORD CD3-108 API Well Number 50-103-20507-00-00 Inspector Name: Lou Laubenstein Permit Number: 205-033-0 Inspection Date: 2/10/2018 Insp Num: mitLOL180212122759 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Type J g 2050330 Type Test SPT TVD !--- 6695 Timing 2152 2152 2152 2152 Well i CD3-108 T e In' v PTD Test psi: 3000 IA 500 3300 3180 3160 BBL Pumped: 3.5 BBL Returned: 3.5 OA 1 512 539 . 539 - 539 - Interval REQVAR P/F P Notes: MITIA per AIO 30.008 to maximum anticipated injection pressure SCANWIELI II it Tuesday,February 20,2018 Page 1 oft • • �3033 27 WELL LOG TRANSMITTAL#904005208 To: Alaska Oil and Gas Conservation Comm. June 12, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 RECEIVED Anchorage, Alaska 99501 DATA LOGGED JUN 2 2 2017 6 2 /21311 M.K.BENDER AOGCC RE: Leak Detect Log with ACX: CD3-108 Run Date: 4/29/2017 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage,AK 99518 CD3-108 • Digital Data in LAS format,Digital Log Image file, Interpretation Report 1 CD Rom 50-103-20507-00 Leak Detect Log with ACX 1 Color Log 50-103-20507-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518JULWe 1 12017 Office: 907-275-2605 :St Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: MAL.....,</) 6e,..ureve • • or T4 41-Iy//,' THE STATE Alaska Oil and Gas ,40, - � ofLASKA Conservation Commission , 2 -- _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 7w AL Fax: 907.276.7542 www.aogcc.alaska.gov Travis Smith Well Integrity Supervisor ConocoPhillips Alaska, Inc. SCANNED l IJN 0 9 2U!!, P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CRU CD3-108 Permit to Drill Number: 205-033 Sundry Number: 317-217 Dear Mr. Smith: 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, PLh Cathy P Foerster Chair DATED this day of June, 2017. RBDMS LI— JUN - 7 2017 • • RECEIVED STATE OF ALASKA MAY Q 2 2Q 7 �� s ALASKA OIL AND GAS CONSERVATION COMMISSION 1 APPLICATION FOR SUNDRY APPROVALS AOGCC 7 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Tubing Patch ❑.i 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory ❑ Development ❑ 205-0330 • 3.Address: g p ❑ Service 0. 6.API Number: Stratigrahic P.O.Box 100630,Anchorage,Alaska 99510 50-103-20507-00 , 7. If perforating: N/A 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? /� AA' , CRU CD3-108 Will planned perforations require a spacing exception? Yes ❑ No E 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0364471 /ADL0372104/ADL0372105 • Colville River Field/Fiord Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depp,P;D $1(ft): Effective Depth MD: Effectiveeej TVD: MPSP(psi): Plugs(MD): Junk(MD): 18,915 �`00.6,9988b� ,6 18,915 '991& rig 3,000 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 70 16 114 114 Surface 3,037 9-% 3,075 2,431 3,520 2,020 Intermediate Production 11,040 7 11,076 6,998 7,240 5,410 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11,076'-18,915' 6,816'-6,998' 4-'/2 L-80 10,097 Packers and SSSV Type: A-1 Inj.Valve in DB-Nipple Packers and SSSV MD(ft)and TVD(ft): Inj.Valve 2,267'MD; 1,929'TVD Baker Premier Packer Packer 10,037'MD;6,695'TVD 12.Attachments: Proposal Summary U Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service E 14.Estimated Date for 15.Well Status after proposed work: 6/9/2017 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG 0 =fir GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Travis Smith Contact Name: Travis Smith/Rachel Kautz Authorized Title: Well Integrity Supe Contact Email: N2549conocophillips.com Contact Phone: 659-7126 Authorized Signature: %fir Date: ,5 Zy� ; COM SSIO USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ 141. q. Other: 4 rficr— 36 cicv`�( t^^ a ,- u''to ri o in !vl-Z r'n C c i r� , 6 F T CPA J 1-0 1V1i iOt rc JCa r-r i'S1po r,ctrvtc- w r Ili AOChCt to Ccsyt cc I 4117 ,3O.005 0 h ci rc fvrin kyr lI -10 WA-6 .7".11-E/5 If no ConWivt7sCQ f-1or, s'5 cLc1-r(t-rd Post Initial Injection MIT Req'd? Yes II No ❑ Spacing Exception Required? Yes ❑ No 2, Subsequent Form Required: )0—4 vi, i RBDMS L— I' - 7 2017 ,Q APPROVED SBY `' `/,7 Approved by: r / j .,() CAOMMISSIONE�jR�/ /� THE COMMISSION Date:III 0-40I� O rrL� r'cI ii /� "' " ``l7 Submit Form and Form 10-403 Revised 4/2017 p r I i id for 12 months.from the date of approval. Attachments in Duplicate • • ConocoPhillips Alaska RECEIVED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 MAY 3 0 2017 AOGCC May 27, 2017 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-403 from ConocoPhillips Alaska, Inc. well CD3-108 (PTD# 205- 0330) for a proposed retrievable tubing patch. Please contact Travis Smith or Rachel Kautz at 659-7126 if you have any questions. Sincerely, ravis Smith Well Integrity Supervisor ConocoPhillips Alaska, Inc. • CD3-108 • SUMMARY OF PROPOSAL Tubing Patch for CRU CD3-108: CRU CD3-108 (PTD#205-0330) is currently a water-only injection well under AIO 30.008 because of TxIA communication on gas injection. Recently CPAI ran an acoustic leak detect log while pumping down the tubing with nitrogen. This LDL indicated a leak was present in the well at 9,928' RKB near the top collar of the GLM in the tubing. CPAI proposes setting a retrievable tubing patch over the leak found on the LDL. Because the well routinely passes MITIAs when on water service, we propose a 30-day monitoring period on MI injection after the patch has been set. If no communication is seen on MI injection, we propose to return the well to normal WAG injection service. 411/ WNS INJ CD3-108 ConocoPhillips 1111/ Well Attributes Max Angle&MD TD Alaska,I(1C, Wellhere APUUWI Field Name Weilbore Status mel(°) MD(MIKE) Act Rlm(ltKD) CR1rn',,,pm 501032050700 FIORD NECHELIK INJ _ 104.85 18,755.45 18.915.0 ••• Comment H25(ppm) Date Annotation End Date KE-Grd(ft) Rig Release Date CD3-10e,5/23120173:4!17 PM SSSV:WRDP Last WO: 43.78 4/11/2005 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation 'Last Mod By End Date Last Tag: Rev Reason:CORRECTED GLV DATE RUN pproven 5/8/2017 (from 6/1/2006 to 5/1/2006) Casing Strings Carting Description OD(In) ID(In) Top(MKS) Set Depth(ftKB) Set Depth(TVD)...WHlen(I...Grade Top Thread CONDUCTOR Insulated 16 15,062 43.8 114.0 114.0 62.5011-40 WELDED `-.MT. 34" HANGER:;,.,— '!" Casing Description OD(In) ID(In) Top(ftKB) set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread SURFACE 95/8 8.921 37.9 3,074.7 2,431.1 36.00 J-55 BTC Casing Description 00(In) ID(in) Top(589) Set Depth(CKB) Set Depth(TVD)..,Wtflen(I...Grade Top Thread PRODUCTION 7 6.276 35.6 11,075.9 6,998.2 26.00 L-80 BTCM Casing Description OD(In) ID(In) •Top(ftKB) 'Set Depth(ftKB) 'Set Depth(TVD)...WttLen(1...Grade Top Thread OPEN HOLE 6 118 6.125 11.075.0 18,915.0 Tubing Strings Tubing Description (String Ma...110(in) (Top(fIKB) !Set Depth(ft..J Set Depth(TVD)(...1Wt(IbHS) (Grade (Top Connection TURING 4 1/2 3.958 32.7 10.096,7 6,722.7 12.60 L-80 (BTM Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (In) 32.7 32.7 0.00 HANGER FMC TUBING HANGER 4.500 2,266.6 1,928.6 52.37 NIPPLE CAMCO'DB'NIPPLE 3.813 "' •-- 10,037.3 6,695.0 61.74 PACKER BAKER PREMIER PACKER 3.875 10,084.4 6,717.0 62.40 NIPPLE CAMCO'XN'NIPPLE 3.725 CONDUCTOR Insulated 34•: 43.8-114.0 10,095.3 6,722.1 62.55 WLEG WIRELINE ENTRY GUIDE 3.875 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 111 Top(TVD( Tap Inel Top(ftK8) (ftK8) (°) Des Com Run Dale ID(In) 2,266.0 1.928.3' 52.36 VALVE 4 1/2"A-1 INJ VALVE(HSS-165)Wf EXTENSION 51312017 1.250 AND DUAL PKG STACKS(77"OAL,PKG 3.61') NIPPLE;2,268,8 VALVE,2.266.0 Mandrel Inserts ISt i o▪f n Top(TVD) Valve Latah Pon Size TRO Run N Top(ftKB) (11KBI Make Modal OD(in) Sere Type Type (in) (psi) Run Date Com 1 9,931.5 6,643.8 CAMCO KBG-2 1 GAS LIFT DMY -BK 0.000 0.0 5/1/2005 Notes:General&Safety End Date Annotation 4/11/2005 NOTE:TREE:FMC/Unihead System w/Horizontal Tree Gen 11/4-1/16"5K 4/11/2005 NOTE:TREE CAP CONNECTION:7"OTIS 5/14/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 SURFACE;37.9-3,074.7) GAS LIFT:9.931.5 HPACKER;10,037.3 NIPPLE;10,084.1 WLEG;10,095.3i I PRODUCTION;35.8-11,075.9 OPEN HOLE;11,075.018,915 0 — • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Sunday,January 15, 2017 7:28 PM To: NSK Problem Well Supv Cc: Senden, R.Tyler Subject: RE:CD3-108 (PTD#205-033) Request for grace period to allow continued MI injection Attachments: image001.png Jan, Unfortunate chain of events. Plan below for continued short term MI injection with DNE limit ip}awed. Regards, Chris SCANNED JAN 2 0201z Original message From: NSK Problem Well Supv<n1617@conocophillips.com> Date: 01/15/2017 4:52 PM (GMT-09:00) To: "Wallace, Chris D (DOA)" <chris.wallace@alaska.gov> Cc: "Senden, R. Tyler" <R.Tyler.Senden@conocophillips.com>,NSK Problem Well Supv <n 1617 @conocophillips.com> Subject: CD3-108 (PTD#205-033)Request for grace period to allow continued MI injection Chris, Alpine injector CRU CD3-108 (PTD#205-033)was reported for exhibiting slow signs of IA pressurization on 12-31-16. An MITIA and packoff tests were performed and passed on 1-12-17 (see attached 10-426), as well as bleeding down the IA pressure for the IA draw down test. Subsequent bleeding, the IA pressure has exhibited further signs of pressurization, although the IA pressure has stabilized below the DNE. The plan is to WAG the well to water injection per the previous correspondence,unfortunately due to circumstances the facility is unable to manage the gas throughput from CD3-108 at this time. CD3-108 is currently taking 14 MMSCFD of miscible gas injection volume—which is -25%of Alpine's overall MI throughput right now. CD2-11 & CD2-15 were both planned to start on MI to absorb some of the gas CD3-108 is currently injecting,but both injection valves failed function testing. Alpine currently has a single slickline unit in the field tied up with CD2-39 pulling a fish lodged downhole. CPAI is pulling an additional slickline crew from Kuparuk to Alpine and prioritizing the slickline backlog to allow for the additional crew to pull &reset the injection valves in CD2-11 & CD2-15 so the wells can start on MI. CPAI requests a one week grace period to leave CD3-108 online in MI service until no later than 1/22/17. The well will still be required to operate with the IA pressure below DNE of 2400 psi. This week grace period will 1 • allow for logistics procuring slickline, the completion of the well work, and unforeseen issues such as weather days. Please let us know if this plan is acceptable. Regards, Jan Byrne/Dusty Freeborn Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907) 659-7126 Cell Phone(907) 943-0450 From: NSK Problem Well Supv Sent: Saturday, December 31, 2016 6:16 PM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: NSK DHD Field Supervisor<NSKDHDFieldSupervisor@conocophillips.com>; Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Subject: CD3-108 (PTD#205-033) IA pressure build-up Chris, 2 Alpine injector CRU CD3-108 (PTD#205-033)has exhibited signs of slowpressurization while on MI � injection. DHD will perform initial diagnostics on the well, which will include an MITIA, DDT, and packoff tests, as soon as reasonably possible. Following the diagnostics, we will commence a 30-day monitor period on MI to determine if TxIA communication exists. Should TxIA communication become apparent while injecting MI,the well will be WAG'd to water injection for a 30-day monitor period to determine if the well has integrity while on water injection. Attached are a 90 day TIO trend and wellbore schematic. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz Well Integrity Engineer,ConocoPhillips Alaska,Inc. Temp. Slope Phone: 907-659-7126 (Filling in for Dusty Freeborn/Jan Byrne) 3 W ULU _ _ • S ~ ¢ U1 co UJ S2 cc CC CC y W W W 4 _ _ U u7 O O taa 0 u7 tri CC LC, LOa Ei Q C/1 tri O O w d LO to Cc c^, r- n- a e- L O 6i 2 a to m en -. o0 w O O GC O (T C7 11 N N N I- I- r-_ r- co 0 o 0 L (NJ N N S CV ,- n H •- •f (V N G CO CO CO — o 0 0 J J C'7 C`-7 co 'U 0 0 0 Ci C3 t, ABap 'S C I 6 t) tJ R Li. tG c la LL I { r- r- ' c c i .; it, ID ` V C Q? tc, co Z y u U ! O C O i+ C I 0 E 1 i , m o j 1 V a_ o C Z C Q : fi 1 • ,, t w u. LO 8 b 0 0 0 ' N O N " 1} i 0 -- r V `o - q tS C�^ r OS I tp itiz O m tp� t7 i� in u u [, a m .. C a ar, b t, Cl u, a:na aaxa _ u', V !9 r, c a r� c6 C !Sd Cf) O w · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ º~ - 0:=3:3 Well History File Identifier Page Count from Scanned File: J OD (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ES (Maria) Date 5/ d.- Of 107 If NO in stage 1, page(s) discrepancies were found: YES Organizing (done) o Two-sided 1/1" 1/11111111111I R~CAN \Ø' Color Items: o Greyscale Items: DIGITAL DATA 0Diskettes, NO'd- o Other, NolType: o Poor Quality Originals: o Other: NOTES: Date 0~1/07 Date sf d1io 7 3 x30=_ qD + Date S/+1/()7 BY: ~ Project Proofing BY: 0riãJ Scanning Preparation BY: ~ Production Scanning Stage 1 BY: Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Date: Maria Comments about this file: o Rescan Needed '" 11111111/1111111 OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: mf ,~IIIIIIIIIIIIIIIII vrrf 151 q = TOTAL PAGES q c¡ (Count does not include cover sheet) t A J1 Jf) 151 V V VT III 11111111111 1111I 151 mf NO 151 1111111111111111111 1111111111111111111 151 Quality Checked 1IIIIII111111111111 10/6/2005 Well History File Cover Page. doc • • MEMORANDUM TO: Jim Regg ~~ S~i `~' ~~~ P.I. Supervisor FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, April 28, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD3-108 COLVILLE RIV FIORD CD3-108 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~ Comm Well Name: COLVILLE RIV FIORD CD3-108 API Well Number: 50-103-20507-00-00 Inspector Name: Bob Noble Insp Num: mitRCN100427182548 Permit Number: 205-033-0 Inspection Date: 4/25/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well L CD3-los iType Inj. O T'VD 6695 ~ jA 1355 2110 2070 2070 P.T.D~ 2050330 TypeTes SPT TCSt pSl ~ 2110 ./ I OA 515 - 525 525 525 Interval axRTST p~F P .Tubing z7zs zrzs z7zs 27zs Notes: N1~ r~ ~ ~'y ~C~ ~eSd~- ~~ s~~~ G(; ~? 3~s k, s - Wednesday, April 28, 2010 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Alpine /CRU /CD3 04/25/10 Colee /Phillips AES Bob Noble • ~fl,s- b `33 Packer Depth Pretest Initial 15 Min. 30 Min. Well CD3-108 Type Inj. G TVD 6,695' Tubing 2,725 2,725 2,725 2,725 Interval 4 P.T.D. 2050330 Type test P Test psi 1,674 Casin 1,355 2,110 2,070 2,070 P/F P Notes: OA 515 525 525 525 Well CD3-110 T pe Inj. W TVD 6,759' Tubing 2,300 2,300 2,300 2,300 Interval 4 P.T.D. 2050410 Type test P Test psi 1,690' Casing 695 1,800 1,745 1,740 P/F P Notes: OA 510 520 520 520 Well CD3-305 Type Inj. G TVD 6,307' Tubing 2,500 2,500 2,500 2,500 Interval 4 P.T.D. 2081930 Type test P Test psi 1,577' Casin 570 1,900 1,870 1,860 P/F P Notes: OA 455 582 577 577 ~~ TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D =Drilling Waste M =Annulus Monitoring I =Initial Test G =Gas P =Standard Pressure Test 4 =Four Year Cycle I =Industrial Wastewater R =Internal Radioactive Tracer Survey V =Required by Variance N =Not Injecting A =Temperature Anomaly Survey T =Test during Workover W =Water D =Differential Temperature Test O =Other (describe in notes) Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Tuesday, April 27, 2010 5:14 PM To: Regg, James B (DOA); Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Cc: NSK Problem Well Supv; NSK Well Integrity Proj; ALP DS Lead and Simops Coord Subject: Alpine State Witnessed MITs Attachments: CRU CD3 Pad 04-25-10.x1s Attached for your records is the Alpine MIT form for tests witnessed by Bob Noble on 04-25-10. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 Page 1 of 1 Maunder, Thomas E (DOA) From: Gaiiunas, Elizabeth C [Elizabeth.C.Galiunas@conocophillips.com] Sent: Tuesday, April 21, 2009 9:45 AM To: Maunder, Thomas E (DOA) Cc: McKeever, Steve; Anderson, Nina M; Kemner, Tyrone T. Subject: CD3 Permafrost and CD3-304 SSSV placement Attachments: CD3-108 BHP with temp TVD log.xls Hi, Tom, I-~ c~d,s ~-d "~~ Here is the information we discussed yesterday. The plan is to set the BAL-O wireline retrievable SSSV at 1600' MD / 1509' TVD. Attached is the temperature log data for CD3-108. From the data it appears the permafrost on CD3 is closer to 1000' or less. The SSSV wilt be set around 500' TVD below the permafrost. I trimmed down the BHP data, since the file was too large to send. Let me know if you have any comments or questions. Liz Galiunas Alpine Drilling Engineer ConocoPhillips Alaska Office: 907-265-6247 ~ ~. `i?~';,~' .~' ~ ~ ; _ ~ ~' Cell: 907-903-1200 6/lb/2U09 2~ S-O~~ CD3-108 Temperature Log SSE G~ S~ ~.~~ ~~~ ~ ~ ~ -d 100 95 90 85 80 75 ~ 70 d ~ 65 r ca a 60 E m ~ 55 50 45 40 35 30 25 100 350 599 845 1077 1295 1489 1669 1827 1980 2138 2293 2447 2599 2750 2901 3055 3209 3364 3519 3679 3842 4003 TVD • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Apri16, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: L~ ._~-, ~~- APR ~ ~ 2005 ~h~r _ ~~s~C?33 C~3 y I o~ Enclosed please fmd a spreadsheet with a list of wells from the Coville River Unit (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with 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 Apri15~`, 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, MJ Loveland 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 4/6/2009 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 CD3-301 206-020 9" NA 9" NA 0.85 4/5/2009 CD3-302 206-010 5" NA 5" NA 0.43 4/5/2009 CD3-303 208-013 9" NA 9" NA 1.70 4/5/2009 CD3-305 208-193 8" NA 8" NA 0.85 4/5/2009 CD3-316A 208-011 26" NA 26" NA 8.93 4/5/2009 CD3-107 206-189 34" NA 34" NA 11.05 4/5/2009 CD3-108 205-033 10" NA 10" NA 1.26 4/5/2009 CD3-109 205-059 9" NA 9" NA 2.13 4/5/2009 CD3-110 205-041 4" NA 4" NA 0.43 4/5/2009 CD3-111 206-030 5" NA 5" NA 0.85 4/5/2009 CD3-112 206-032 3" NA 3" NA 0.43 4/5/2009 CD3-113 207-004 14" NA 14" NA 1.28 4/5/2009 CD3-114 207-033 5" NA 5" NA 0.85 4/5/2009 CD3-115 209-006 8" NA 8" NA 1.28 4/5/2009 CD3-117 209-026 6" NA 6" NA 0.43 4/5/2009 CD3-118 208-025 8" NA 8" NA 0.85 4/5/2009 .~.'" . `~ .,~ ~"" ,/, MeN) DATA SUBMITTAL COMPLIANCE REPORT 5/2/2007 'SfJ- ':<Á.~NJ~~~ API No. 50-103-20507-00-00 Permit to Drill 2050330 Well Name/No. COLVILLE RIV FIORD CD3-108 Operator CONOCOPHILLlPS ALASKA INC Current Status WAGIN ' Q ------==-~------==== -~---- MD 18915 0./' TVD 6816 ~ Completion Date 4/11/2005 r Completion Status WAGIN _._.---'~-----~~-~ REQUIRED INFORMATION Mud Log Yes Samples No Directional surv~ - -~---~ ~-- - ----- .~,--~ DATA INFORMATION -~--_.'~~--_._~- ---~ ---~---_._-.__.._----~------ (data taken from Logs Portion of Master Well Data Maint Types Electric or Other Logs Run: GR/Res, Dens/Neutron Well Log Information: Log/ Data Digital Type Med/Frmt ~-D Asc £t,¿' JZDD. CD Asc íU Lis ~. C Pdf I i / .,f{Og I I I flìr. Ii., 1a162 Induotion/Rc3i!tivity ¡L l)ì4).., ~pt ~ kfr! ~ LIS Verification ~b C ~~¡"'Ij 14452 Induction/Resistivity I I ---~--~.... e Electr Dataset Number Log Log Run Interval OH/ Scale Media No Start Stop CH ----~ 0 18915 Open 0 18915 Open 218 18915 Open Received Comments 5/4/2005 IIFR Name Directional Survey 5/4/2005 2/22/2006 MWD ROP DGR EWR SLD CTN plus Graphics SURFACE WELL TESTING REPORT, POWERWELL SERVICES CEMENT BOND LOG W/SBHP SLIM CEMENT MAP TOOL Directional Survey 13742 Induction/Resistivity 13100 See Notes o o Case 6/15/2005 Cement Evaluation Col 10530 Case 4/28/2005 o 11'5 18915 Open .6/10/:ilQO& c 115 18915 Open 6/10/2005 115 18915 Open 1/29/2007 LIS Veri, ROP, NPHI, NCNT,RHOB,DRHO,GR - w/Graphics Well Cores/Samples Information: _.._-----,-_.,-_.._-~----'-------- Name 1--- Cuttings L__~__ Interval Start Stop 870 18915 Sample Set Received Number Comments Sent 3/29/2006 1170 ----I ----~ --- ~--~_. ADDITIONAL INFORMß'ON Well Cored? Y\(ß) Daily History Received? ~ Formation Tops ~ Chips Received? ~~ Analysis Received? -.::L.J..bV ._----~----~-- -'-~~ Permit to Drill 2050330 MD 18915 TVD 6816 Comments: ---~- Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 5/2/2007 Well NamelNo. COLVILLE RIV FIORD CD3-108 Operator CONOCOPHILLlPS ALASKA INC API No. 50-103-20507-00-00 Completion Date 4/11/2005 Completion Status WAGIN Current Status WAGIN UIC Y ~-- Date: ---~ ;Z3 f-CJ~7 - e - . . ~F?¡" ='-' ,,,",~ ."..,,; ~,,., ( j '~'\ -;~iE';:) '1"1{;)" WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 16,2006 RE: MWD Formation Evaluation Logs: CD3-108, CD4-318_PBl. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 CD3-108: U"" c... 965--033 tt 14t.1Çé). Digital Log Images: 50-103-20507 -00 1 CD Rom CD4-318_PB1: ~S--lq0 It 1£../LfS-3 Digital Log Images: 50-103-20519-00,70 1 CD Rom :;) . . das-a~ -:, MECHANICAL INTEGRITY REPORT -.. 'i\''ELL NUH13 ER ~ Ç' t\l-. (. Q ~ 'Ç$2) ~ - \.J~C~ c $ .~ - \(J~" :. ~ G 2 S ~ :::;._:: ~ : :; j,);) ~ 0 ç-' 11(\\-0S- OPER & FIELD -~UD ~.~- ..: ~ i.J .-. ~ :- : d, TD: \'6<;\ ~MD <0 ~\ ~ TVD; :?BTD: Shoe: \ \a\~ rID G q<;<6TIlD j DV: _::..:¡e::::-: Shoe: ill) TVD; ~'"".,.... ~ v.r : MD TVD till ·TV"D HD ";:',i'0 -,.; t..LL DATÞ_ C¿SÜ~6: '\ i...1 \ ~\ _ '.J 0 2..", g : '\ b P aCKe:!:' c. $, \\ :":'ole Siz.e 0 d - \(J'(J~,,\~ ,<0<;') TVû; Set é.L: ana i Pe!:'£.s o \,Cc '<'- \\ 0\ <0 \\JO~ '\ to ~(:) \<e, \ ~-~ \ c:;-- ~C7.ÞJEC~-.L INTEGRITY - PÞ:.RT !l Annulus Press Test: ~~ 15 Dlln 30 illl.ll COü:iI:lents: ----- ~CHÞ~ICÞ~ INTEGRITY - PART !Z \ ") ~ \ \ \5 -:.. 5 d b ~ \ S C e!11enc Volumes:' .Amt. Liner Cs g JSL\ ~'-{ ; DV Cwe -,¡01 to cove:è:' pe:!:'':s ~)(y~o).~ ~~~~\~? '':>Cç "...,..') t:\'Cc..es"';:(J..ï -\0 a:>~(.XS\.c-1\~~\\L~~~...J\L (, \0 \ '-\ ~ ¡¡v..~ ~ S(')(') \ IQeo!:'etical Toe C s() (c::.~ <::> k\xr~~\,C':'- \\tjC ' S ·~O"> Ce!11eDt Bond Log (Yes or No) '(~S \7\ Q~ ~ ~ '\ \? {'Q '-0... \-k0 CEL ~v2.luatl.on, z.one ¿Dove perfs 1-\ \ '-\ I () 5'" ; In AOGCC File"'¿~<-- '-XJ.."""~~ ~~'''''> ,,~ "«::,¿~ ,\"-~,,,,:>~ \ \ \J :::){J'CJ- \ CJ5'~ (J 1( Proàuction Log: Type Evaluation CONc,LUSIoriS: ?art: tl: N\\'\ \>~~,~~~ \$(.~ --0 c.o , ? ar:: I Z, v-.r\..,,, ~ ~"-ú. \SJ tft"Yll\ 1;¡-<-íC) "" MEMORANDUM . State of Alaska a Alaska Oil and Gas Conservation Commi~ TO: limRegg ~, ¡cliC(k1C... P.I. Supervisor (.cCrt DA TE: Tuesday, October 03, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD3-J08 COLVILLE RlV UN FIORD Cm-l08 FROM: 10hn Spaulding Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv .J6J2- Comm G 63-- I US NON-CONFIDENTIAL Well Name: COLVILLE RIV UN FIORD CD3- API Well Number 50-103-20507-00-00 1AD Insp Num: mitJS061001100809 Permit Number: 205-033-0 ReI Insp Num Inspector Name: John Spaulding Inspection Date: 9/29/2006 Packer ~Í\S0 Well I cm-I08 iType Inj. ! w : TVD -T~! IA I 1265 P.T. ! MOD' :TYP'T...jSeT T..t p;; : (" I OA Inte1:~ INITAL PIF _ P / _ Tubing I ]049 Notes ,.. \ (pia c,,<:> ~J 1£"""1, \ /-;A Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 2880 2850 2847 -~-~-~ 522 623 623 623 1049 J040 1046 , -,~~ Tuesday, October 03, 2006 Page I of 1 It - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Emaillo:Winlon_Aubert@admin.slale.ak.us;Bob_Fleckenslein@admin.slale.ak.us;Jim_Regg@admin.slale.ak.us;Tom_Maunder@admin.slate.ak.us OPERATOR: çonocoP.þillips FIELD / UNIT / PAD: Alpine/ CRU I CD3-108 DATE: 09/29/06 OPERATOR REP: Mike Mishler AOGCC REP: John Spalding Packer Depth Pretest In ilia I 15 Min, 30 Min. wellCD3-108 Type Inj, W TVD I 6,695' TUbingl 2.2351 1,049/ 1.0401 1.0461 I P,T.D, 2050330 Type test P Test psi 3000 Casing 1.265 2.880 2,850 2,847 P Notes: OA weill Type Inj. I T:~PSil TUbingl I I I I Inlerval P.T.D. Type test Casing P/F Notes: OA weill I Type Inj. I T:~PSi TUbing I I I I Inlerval P,T.D, Type test Casing P/F Notes: OA well Type Inj,/ I T:~PSil TUbing I I I I Inlerval P.T,D. Type lesl Casing P/F Notes: OA weill Type Inj, I T:~PSil I TUb~ngl I I I Interval P.T,D, Type lest Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waist G=Gas I = Industrial Waistewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = standard Pressure Test R = Internal Radioactive Tracer SUlvey A = Temperature Anomaly Survey D" Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT Report Form BFL 9/1/05 MIT CRU CD3-108 09·29-06,xls e ~ ConocoPhillips Alaska, Inc. e Bayview Geological Facility 619 East Ship Creek Ave" Suite 102 Anchorage, AK 99510 phone 907,263,4859 TRANSMITTAL TO: AOGCC 333 W 7TH AVE Anchorage, AK 99501 OPERATOR: CPAI SAMPLE TYPE: DRIES SAMPLES SENT: Dries 870'-18,915' SENT BY: D, L. PRZYWOJSKI DATE: 29 MARCH 2006 AIRBILL: 5325490 CPBV 06-03-29-05 CHARGE CODE#: 10105440 WELL: CD3-108 NUMBER OF BOXES: 12 I 4 , '70 .--- / L UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COpy OF THIS FORM TO: RECEIVED BY: ~()JI ConocoPhilIips Alaska, Inc. 619 E. Ship Creek Ave Anchorage, AK. 99510 Attn: Dan Przywojski DATE: ~C( /1J Àö~f¿1 ).ß ~- - I» 3 . . Note to File CRU CD3-108 205-033 50-103-20507-00 March 15,2006 Examination ofthe well file indicates that a mudlog and cuttings samples were required on this well (see the permit checklist and the 10-401 form). A check of Commission files indicates that no mudlog or samples were submitted. I phoned Vem Johnson at ConocoPhillips. He stated that is was an oversight, no mudlog had bee acquired. ConocoPhillips will attempt to have equipment in place to mudlog the up-coming CD3- 112 well, which will spud the week of March 22, 2006. I told him ifthat is not practical, to collect a mudlog and samples on a future well from this pad. Steve Davies March 15, 2007 . . ~ ConocoPhillips Casing Detail 9 518" Surface Casing Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Doyon 19 RKB to Landing Ring FMC Gen V Hanger Jts 3 to 72 70 Jts 9-5/8" 36# J-55 BTC Csg Weatherford Float Collar Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg Ray Oil Tools "Silver Bullet" Float Shoe TD 12 1/4" Surface Hole 9-5/8" Shoe @ 3075' MD / 2431' TVD RUN TOTAL 43 BOWSPRING CENTRALIZERS· 1 per jt on Jt #1 . #12 (stop ring on Jt #1 & 2) and over collars on jts# 14,16,18,20,22,24,26,28,30, 32,34,36,38,40,42,44,46,48,50,52,54,56,58,60,62 64, 66, 68,70 82 joints in the pipe shed. Run 72 joints· 10 joints stay out ,",,"'-> \ '"'-\o{ \I'--\,n\-<\ ('}r--. ~\T)'h~kS) '\11'\ ~·.)Q~C)M C~ ~ \) o~\' \ t-c("~~,C',(' ~r- \:...\) S -\O~~.. .AA r {l¡ r..-O~ ll> Use Best-a-Life 2000 pipe dape MU torgue - 8600 ftllbs Remarks: Up Wt - 160k Dn Wt - 137k Block Wt - 75k d05·~Os -:s Well: CD3-108 Date: 3/24/2005 LENGTH 37.90 2.22 2950.82 1.49 80,02 2.29 Supervisor: L Hill / M. Thornton DEPTH TOPS 37,90 40,12 2990,94 2992.43 3072.45 3074.74 3084.74 . . ConocoPhillips Alaska Cementing Report Legal Well Name: CD3-108 Common Well Name: CD3-108 Event Name: ROT - DRILLING Primary Hole Size: 12,250 (in) TMD Set: 3,075 (ft) Date Set: 3/25/2005 Csg Type: Surface Casing Csg Size: 9.625 (in.) Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger Rot Time Start: : Rec Time Start:22:45 Report #: Start: 1 3/19/2005 Cement Job Type: Primary Squeeze Open. Hole Hole Size: sa TMD: (ft) sa Date: sa Type: Cmtd. Csg: Cementer: Steve Time End: : Time End: 02:00 RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: 20.0 (ft) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Drag Up: 160,000 (Ibs) Drag Down: 137,000 (Ibs) Type: Cement Casing Volume Excess %: 300.00 Meas, From: 213 Time Circ Prior To Cementing: 2.00 Mud Circ Rate: 294 (gpm) Mud Circ Press: 350 (psi) Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd, Csg: Page 1 of 3 Spud Date: 3/18/2005 Report Date: 3/25/2005 End: 4/11/2005 Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd, Csg: Pipe Movement Pipe Movement: Reciprocating 1 Stage No: 1 of 1 Start Mix Cmt: 01 :40 Start Slurry Displ: 01:41 Start Displ: 02:50 End Pumping: 03:30 End Pump Date: 3/25/2005 Top Plug: Y Bottom Plug: Y Type: Spud Mud Density: 9,6 (ppg) Visc: 110 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type:Mud Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 6,00 (bbl/min) 7.00 (bbl/min) Y 560 (psi) 1,100 (psi) 5 (min) Y ................. Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: 213.00 (bbl) .....-- -..... Ann Flow After: N Mixing Method: RCM Density Meas By: Densometer PV/YP: 20 (cp)/18 (lb/100ft2) Gels 10 sec: 9 (lb/100ft2) Gels 10min: 10 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.6 (ppg) Volume: 233.80 (bbl) Mud Data Stage No: 1 Slurry No: 1 of 4 To: (ft) Description: Biozan water Cmt Vol: 40.0 (bbl) Density: 8,30 (ppg) Slurry Vol: (sk) Water Vol: (bbl) Class: Yield: (ft'/sk) Other Vol: 0 Temperature: (OF) Temperature: ("F) Temperature: ("F) Time Compressive Strength 1: Compressive Strength 2: Purpose: Flush Mix Water: (gal) Foam Job: N Temp (OF) ("F) Pressure (psi) (psi) Printed: 1/11/2006 11:14:54 AM . . ConocoPhillips Alaska Cementing Report Legal Well Name: CD3-108 Common Well Name: CD3-108 Event Name: ROT - DRILLING Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) To: (ft) Water Source: Lake Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Page 2 of 3 Report #: Start: 1 3/19/2005 Spud Date: 3/18/2005 Report Date: 3/25/2005 End: 4/11/2005 Stage No: 1 Slurry No: 2 of 4 Description: MUDPUSH XL Class: Cmt Vol: 50,0 (bbl) Density: 10,50 (ppg) Yield: (fP/sk) Slurry Vol: (sk) Water Vol: 50.0 (bbl) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp ("F) (OF) Stage No: 1 Slurry No: 3 of 4 Slurry Data Fluid Type: LEAD Slurry Interval: 2,668.00 (ftJl'o: 36,00 (ft) Water Source: Lake Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Trade Name 0-53 0-46 0-79 S1 0-124 0-44 0-65 Slurry Data Fluid Type: TAIL Slurry Interval: 3,075,00 (ftJl'o: Water Source: Lake Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Description: ASLite Cmt Vol: 414.0 (bbl) Slurry Vol:522 (sk) ~ Temperature: (OF) Temperature: (OF) Temperature: (OF) Class: G Density: 10,70 (ppg) Yield: 4.~5 (ft3/sk) Water Vol: 250.4 (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Temp ("F) (OF) Stage No: 1 Slurry No: 3 of 4 - Additives Type GYPSUM DEFOAMER EXTENDER ACCELERATOR FILLlTE ACCELERATOR DISPERSANT Concentration Uhits 30,00 % 0,60% 1,50% 1.50% 43,00 % 9,00 %BWOW 0,50% Stage No: 1 Slurry No: 4 of 4 Description: 2,667,00 (ft) Cmt Vol: 50,0 (bbl) Slurry Vol239 (sk) ----- Temperature: ("F) Temperature: ("F) Temperature: ("F) Class: G Density: 15,80 (ppg) Yield: ~k) Water Vol: 29,5 (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Temp (OF) ("F) Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Purpose: PRIMARY Mix Water: 20,15 (gal) Foam Job: N Pressure (psi) (psi) Units Purpose: PRIMARY Mix Water: 5.10 (gal) Foam Job: N Pressure (psi) (psi) Printed: 1/11/2006 11 :14:54 AM . . ConocoPhillips Alaska Cementing Report Page 3 of 3 Legal Well Name: CD3-108 Common Well Name: CD3-108 Event Name: ROT - DRILLING Report #: Start: 1 3/19/2005 Spud Date: 3/18/2005 Report Date: 3/25/2005 End: 4/11/2005 Stage No: 1 Slurry No: 4 of 4 - Additives Trade Name Type DEFOAMER DISPERSANT ACCELERATOR Concentration 0,20% 0.30% 2.00% Units Units 0-46 0-65 S1 Casing Test Shoe Test Liner Top Test Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: Log/Survey Evaluation Interpretation Summary CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Remarks Cement 9 5/8" casing as follows: Pumped 40 bbls, biozan water wI nut plug - 6 bpm @ 240 psi wI rig pump - Switch to Dowell - Pumped 3 bbls water - test cement lines to 3000 psi - Dropped btm plug - Mixed & pumped 50 bbls Mudpush XL spacer @ 10,5 ppg - 5,0 bpm @ 175psi- Mixed & pumped 414 bbls of lead slurry (ASL "G" wI 30% 0-53, 0.6% 0046, 1.5% 0079, 1,5% S001, 43,1 % 0124, 9% BWOW 044, 0,5% 0-65) @ 10,7 ppg -7.5 bpm @ 50 - 350 psi - switched to tail slurry & Pumped 50 bbls ("G" wI 0.2% 046, 0.3% 065, 2% S001) @ 15.8 ppg - 5.2 bpm @ 465 - 515 psi Dropped top plug & pumped 20 bbls water wI Dowell - Switch to rig pumps - Displaced wI 9,6 ppg mud @ 7 bpm 420 to 770 psi for first 200 bbls - slowed to 3 bpm @ 560 psi for last 13 bbls, Total displacement 233.8 bbls- Bumped plug tl1060 psi - CIP @ 03:30 hrs 3/25/05, floats helds. Full returns during job w/213 bbls cement returns to surface - recripcated pipe until 319 Bbls leadl slurry pumped, landed hanger on landing ring. Good returns, " Printed: 1/11/2006 11 :14:54 AM . . ConocoPhillips Alaska, Inc. Daily Drilling Report I JOB NUMBER I EVENT CODE 124 HRS PROG TMD I TVD I DFS CD3-108 ODR 3,085.0 2,437,0 3.20 SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAILY TANG L, Hill I M, Thornton doyon1@ppco,com 19 Alpine 19,769.0 0 CURRENT STATUS ACCIDENTS LAST 24 HRS,? DAILY INT WIO MUD WELL NAME Picking up 4" drill pipe. o 24 HR FORECAST P/U 4" DP, P/U BHA, Drill shoe track, LOT, Drill 8-1/2" hole LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP LAST SURVEY: DATE TMD INC AZIM I LAST CASING 3/24/2005 3,014.65 51,930 44,570 9,625 (in) @ 3,075.0 (ft) - DEN~ITY(ppg) [ 9.50 Ipp[ [ECD I [MUD DATAl DAILYCOSr [ Fvl pV/yP .../ GiELS I WUHTHPI FCIT3'/SOLI OILiW/· AT I %OS,a5n/·2d7/M.5BT I P9h.IOP/M 97 . 20/18· 59/87 .... 8.21 OPERATIONS StlMIMARY PHASE SURFAC Circ & condo mud for cement, Stage rate up f/5 bpm @ 310 psi to 6 bpm @ 250, Reciprocate casing 20', UP 160K, ON 137K. SURFAC Held PJSM wI all personnel, Pump 40 bbls biozan water wI nut plug at rate of 6,0 bpm @ 240 psi with rig pump, Swith to Dowell & pump 3 bbls water, Test lines to 3000 psi, Drop btm plug, Mix & pump 50 bbls 10,5 ppg MudPUSH XL at rate of 5,0 bpm @ 175 psi, Mixed & pumped 414 bbls (522 sxs) 10,7 ppg Lead slurry plus additives at rate of 7,5 bpm @ 50 to 350 psi, Observed nut plug at shakers after pumping 357 bbls lead, Stopped reciprocating casing after pumping 319 bbls lead (82 bbls lead around shoe) due to decrease in down weight, Switched to Tail & pumped 50 bbls (239 sxs) plus additives at 15.8 ppg at rate of 5.2 bpm @ 465 to 515 psi, Shut down & drop top plug, Displace plugs wI 20 bbls fresh water, Switch to rig pumps & displace wI total of 213,8 bbls 9.6 ppg mud at rate of 7.0 bpm @ 420 to 770 psi, Slowed rate down to 3 bpm @ 560 psi on last 13 bbls, Bumped plug wI 1060 psi, C,I.P @ 03:30 hrs 3/25/05, Floats held OK, Had full returns thru out job wI 213 bbls good cmt returns to surface. SURFAC Rig & test 9-5/8" casing to 2500 psi for 30 min, SURFAC Rig down Dowell cement head, Lay down landing joint, Flush out cmt fl diverter& riser. SURFAC Nipple down diverter system. SURFAC Resurvey conductor for wellhead alingment. SURFAC Install & test FMC Gen. Wellhead, Install & nipple up BOPE, SURFAC Rig & Test Hydrill to 250 psi low & 3500 psi high, All other BOPE equip, to 250 psi low & 5000 psi high, Lay down test joint, Install wear bushing. SURFAC Pick up short bails & elevators, Pick up 4" drill pipe from pipe shed, 24 HR SUMMARY: Circ & Cond, mud fl cmt, Cmt 9-5/8" csg wI 213 bbls cmt to surface, Test csg f/30 min, Nipple down diverter, Survey wellhead alingment, Nipple up BOP, Test BOP, P/U 4" D.P. FROM TO 00:00 01 :00 CODE 'TROUBLE' SUB CEMENT P CIRC HOURS 1,00 01 :00 03:30 2.50 CEMENT P PUMP 03:30 04:15 0.75 CASE P MIT 04:15 06:00 1,75 CEMENT P PULD 06:00 09:30 3.50 WELCTL P NUND 09:30 13:30 4,00 WELCTL t\ P OTHR 13:30 16:15 2.75 WELCTL P NUND 16:15 22:30 6.25 WELCTL P BOPE 22:30 00:00 1.50 DRILL P PULD COMPANY ConocoPhillips Company Fairweather E&P Service Doyon Drilling Inc ACI - Arctic Catering Halliburton - Sperry-Sun SERVICE DATE OF LAST SAFETY MEETING DAILY TOTAL 3/25/2005 291,834 I LEAKOFF AFE 10066940 I NEXT CASING 7,000 (in) @ 11,085.0 (ft) o I CUrvlCOST I Pf/Mf CI I cal 0.051 PERSONNEL DATA NO. HOURS COMPANY Halliburton - Sperry-Sun 2 M-I Drilling Fluids 25 Swaco 5 Dowell 2 Alaska Clean Seas SERVICE of 2 REPT NO, I DATE 5 3/25/2005 I CUM. TANGO CUM INTANG WI MUD o CUM COST WI MUD 840,459 AUTH. LAST BOP PRES TEST 3/25/2005 o H2sILIMEI ES NO. HOURS 2 2 4 3 2 Printed: 1/11/2006 11 :06:58 AM WELL NAME CD3-108 COMPANY I Epoch Well Services 'nc .. ITEM Fuel Rig Water, Drilling RESERVOIR NAME CD1-19A UNITS gals bbls CD3-108 . ConocoPhillips Aliaska,·lnç. Dally Drilling Report ¡JOB NUMBER I EVE;TDC~DE 124 HRS PROG IT;~085,O SERVICE PERSONNEL DATA NO. I HOURS II .. COMPANY I 1 FMC Corporation Well he USAGE 3,091 140 MATERIALS 1 CONSUMPTION I ON HAND" ITEM I 9,568 II Water, Potable I 990 II Camp fuel RESERVOIR AND INTERVAL DATA ZONE I TOP I BASE I 2415 0 . ITVD IDFS 2,437.0 3.20 SERVICE UNITS bbls gals COMMENTS Page 2 of 2 I REPT ~O. ¡DATE 3/25/2005 NO. I HOURS ON HAND 1,120 Printed: 1/11/2006 11 :06:58 AM PRESSURE I GRITY TEST CONOCOPHILLlPS Alaska, Inc. Date: #2 Mud Pump .... I Pumping down annulus and DP, Casing Shoe Depth I Hole Depth .OlFt-TVD Ft-MD I Ft-TVD 9-5/8" 36#/Ft J-55 BTC ...-1 I Ri9: I Well Name: Drilling Supervisor: Type of Test: Casing Shoe Test LOT/FIT ...-, Pressure IntearitvTest Mud Weight: ppg Mud 10 min Gel: Lb/100 Ft2 Rotating Weight: Lbs BlockslTop Drive Weight: Lbs Desired PIT EMW: ppg Estimates for Test: 1075 psi ppg Lb/100 Ft2 psi Lbs Lbs 2 bbls 0.9 bbls EMW :: Leak..off Pressure + Mud Weight :: 956 9 5 0.052 x TVD 0.052 x 2431 + . EMW at 3075 Ft-MD (2431 Ft- TVD):::: 17.1 ppg 3000 - 2500 - 2000· W 0:: :J ø 1500 ø w 0:: a.. 1000 500 Comments: PIT 15 Second Shut-in Pressure, psi 800 Lost 35 psi during test, held _ 98.6% of test pressure, r::- .1~.._.;.....;J.t: = _ _ ~ 2 3 Barrels 4 5 6 7 0 5 10 15 20 25 30 St'll..lt-In time, Minutes o PIT Point "'""III-CASING TEST ~LEAK~FFTEST Volume Input '9' VolumefStroke ----- - -- ---- - -- - -------------------------------:::::J Pump Rate: r Bbls/Strk '9' I Pressure Integrity Test Pumping Shut-in Strks psi Min psi Casing Test Pumping Shut-in Strks psi Min psi Hole Size: i 8-1/2" RKB-CHF:I Ft Casina Size and Description: CasinQ Test Mud Weight: Mud 10 min Gel: Test Pressure: Rotating Weight BlocksfT op Drive Weight Estimates for Test: Volume Pumped 2.5 Bbls Volume Bled Back o 1 2 3 4 5 6 7 8 9 10 15 20 25 30 Volume Pumped 5.8 Bbls Strkjmin 0.00 0,25 0.50 1.00 1.50 2.00 2.50 3.00 3.50 4.00 4.50 5.00 5.50 6.00 6.50 7.00 7.50 8.00 8.50 9.00 9.50 10.00 Volume Bled Back i':iurrace LV I l,;U;;S-l UÖ Summary .... . ~ ConocoPhillips Casing Detail 7" Casino . Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Doyon 19 RKB to Landing Ring FMC Gen V Hanger Jts 3 to 259 257 Jts 7" 26# L-80 BTCM Csg Davis Lynch Float Collar Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg Ray Oil Tools "SHver Bullet" Float Shoe 8-1/2" Hole TD @ 11085' MD 16999' TVD 7" Shoe @ 11075.87' MD 16998' TVD Total Centralizers: 50 blade centralizer per jt on # 1-14 centralizer per jt on # 1 blade centralizer one per jt on every other # 192 to 256 275 Last 16 in shed· 259 total out to run Use Best-a-Life 2000 pipe dope Remarks: Wt - 295k On Wt - 150k Block Wt - 75k TO 8 1/2" Hole Supervisor: D. Mickey / M. Thornton Well: Date: LENGTH 35.58 1.81 10948.33 1,31 86.70 2.14 CD3-108 4/1/2005 DEPTH TOPS 35,58 37,39 10985,72 10987.03 11073.73 11075.87 . Legal Well Name: CD3-108 Common Well Name: CD3-108 Event Name: ROT - DRILLING Primary Hole Size: 8.500 (in) TMD Set: 11,076 (ft) Date Set: 4/1/2005 Csg Type: Production Casing Csg Size: 7.000 (in.) Cmtd. Csg: Production Casing Cement Co: Dowell Schlumberger Rot Time Start: : Rec Time Start:05:53 . ConocoPhillips Alaska Cementing Report Report #: Start: 2 3/19/2005 Cement JobTyp.e: Primary Squeeze Open Hole Hole Size: sa TMD: (ft) sa Date: SO Type: Cmtd. Csg: Time End: Time End: 07:28 RPM: SPM: Type: Cement Casing Volume Excess %: 40,00 Meas. From: Time Circ Prior To Cementing: 1,00 Mud Circ Rate: 252 (gpm) Mud Circ Press: 720 (psi) Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: sa TMD: SQ Date: Cmtd. Csg: Page 1 of 3 Spud Date: 3/18/2005 Report Date: 4/112005 End: 4/11/2005 Plug Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd, Csg: Cementer: Jim Thompson Pipe Movement Pipe Movement: Reciprocating ~\ Start Mix Cmt: 06:25 Start Slurry Displ: 06:25 Start Displ: 06:36 End Pumping: 07:47 End Pump Date: 4/1/2005 T:Jp Plug: Y Bottom Plug: Y Type: Non-Disp. LS Density: 10.0 (ppg) Visc: 42 (s/qt) Bottom Hole Circulating Temperature: ("F) Displacement Fluid Type:Mud Slurry Data Fluid Type: FLUSH Slurry Interval: 8,228,00 (ftyro: Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Init Torque: (ft-Ibf) Stroke Length: 25,0 (ft) Avg Torque: (ft-Ibf) Drag Up: 315 (Ibs) Max Torque: (ft-Ibf) Drag Down: 155 (Ibs) Returns: 100 % Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: Density Meas By: densometer PVIYP: 12 (cp)/19 (lb/100ft2) Gels 10 sec: 9 (lb/100ft2) Gels 10 min: 12 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 10.0 (ppg) Volume: 398,50 (bbl) Stage No: 1 of 1 Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 6,20 (bbl/min) 6,20 (bbl/min) Y 640 (psi) 1,100 (psi) 5 (min) Y Mud Data Stage No: 1 Slurry No: 1 of 3 Description: CW100 7,343,00 (ft) Cmt Vol: 20,0 (bbl) Slurry Vol: (sk) Temperature: ("F) Temperature: ("F) Temperature: (OF) Density: 8,30 (ppg) Water Vol: (bbl) Class: Yield: (fP/sk) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Purpose: Flush Mix Water: (gal) Foam Job: N Temp (OF) ("F) Pressure (psi) (psi) Printed: 1/11/2006 11:15:06AM . Legal Well Name: CD3-108 Common Well Name: CD3-108 Event Name: ROT - DRILLING Slurry Data Fluid Type: FLUSH Slurry Interval: 9,555,00 (ftJfo: Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Slurry Data Fluid Type: TAIL Slurry Interval: 11,075.00 (ffþ: Water Source: lake water Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: ("F) Trade Name 0-46 0-65 B-155 0167 . ConocoPhillips Alaska Cementing Report Report #: Start: 2 3/19/2005 Stage No: 1 Slurry No: 2 of 3 of 3 Spud Date: 3/18/2005 Report Date: 4/112005 End: 4/11/2005 Description: MUDPUSH XL Class: 8,228,00 (ft) Cmt Vol: 30,0 (bbl) Density: 12.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Temperature: ("F) Temperature: (OF) Temperature: ("F) Time Compressive Strength 1: Compressive Strength 2: Stage No: 1 Slurry No: 3 of Description: 9,555.00 (ft) Cmt Vol: 52.4 (bbl) Slurry Vol254 (sk) Temperature: (OF) Temperature: ("F) Temperature: ("F) Temp (OF) (OF) Class: G Density: 15.80 (ppg) Yield: 1,16 (ft3/sk) Water Vol: 30,8 (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Stage No: 1 Slurry No: 3 of 3 - Additives Type DEFOAMER DISPERSANT Concentration Units 0,20 %BWOC 0.30 %BWOC 0.07 %BWOC %BWOC Temp (OF) (OF) Liquid Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Purpose: PRIMARY Mix Water: 5.09 (gal) Foam Job: N Pressure (psi) (psi) Units Printed: 1/11/2006 11 :15:06 AM . . ConocoPhillips Alaska Cemenfng Report Page 3 of 3 Legal Well Name: CD3-108 Common Well Name: CD3-108 Event Name: ROT - DRILLING Report #: Start: 2 3/19/2005 Spud Date: 3/18/2005 Report Date: 4/112005 End: 4/11/2005 Casing Test Shoe Test Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y Pressure: (ppge) Tool: N Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N Log/Survey Evaluation Interpretation Summary CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: N Bond Quality: Temp Survey: N Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Deteclion Indicator: Remedial Cementing Required: N Number of Remedial ~queezes: Remarks Establish circulation - stage pumps up to 6 BPM @ 720 psi - Circulate & condition for cement job - PJSM Cement 7" casing as follows: Pumped 5 bbl CW-100 - Test lines to 370') psi - pump 15 bbls CW-100 @ 4 B/P @ 480 psi - Drop btm plug - Mix & pump 30 bbls MudPush XL @ 12.5 ppg - 4 B/M @ 500 psi - Mix & pump 52 bbl Lead slurry (Class G wI ,2% 0046, .3% 0065, ,07% B155, .4% 0167) @ 15,8 ppg - 5,4 B/M @ 500 psi Drop top plug - Pumped 20 bbls water w/ Dowell - Switch to rig pumps & displaced wI 398.5 bbls 10.0 ppg mud @ 6.2 B/M @ 480 to 780 psi - slowed rate to 3.5 B/M for last 18.5 bbls - 550 to 640 psi - bumped plug w/1100 psi - check floats - OK - CIP @ 0747 hrs, Full returns throughout job Printed: 1/11/2006 11 :15:06 AM . . 2 ConocoPhillips Alaska, Inc. Daily Drilling Report I JOB NUMBER I EVENT CODE 124 HRS PROG TMD I TVD I DFS CD3-108 ODR 11,085,0 6,999,0 10.20 SUPERVISOR I RIG NAME & NO, I FIELD NAME I OCS NO, AUTH MD I DAlL Y TANG D. Mickey I M. Thornton doyon1@ppco,com 19 Alpine 19,769.0 0 CURRENT STATUS ACCIDENTS LAST 24 HRS, ? DAILY INT WIO MUD RIH & Picking up 4" drill pipe, 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL PU 4" DP - MU BHA - PU 4" DP, CIa, FIT, Drill 6-1/8" hole, 4/1/2005 318,162 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE 17,07 10066940 LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING LAST BOP PRES TEST 3/29/2005 11,056.70 84,620 323,620 7.000(in)@ 11,075.0(ft) 4,500(in)@ 10,112,O(ft) 4/1/2005 DENSIT'f(p.p~)·1 10,00 I PP I ECD I MUD DATAl DAILYCOS'r 0 [cuMcos'rl 0 :: I ~;/~:I :~~sl ~~:;P I FC~~SOL OIU;AT I %~~~;~M:T I P;,:/M ~f~:; CI I Cä I H2S I LIME I ES BHANO. 3 I BHA! HOLE CONDITIONS IBIINO. I 3 BHA W'rlBELOVVJARS! STRING WLUP STRINGWT. DN I STRING WT. ROT TORQUE/UNITS BHA LENGTH 375.71 ITEMDESCRIP'rION NOiJTS LENGTH CONNSIZE CONN TYPE 1 1.20 6.125 3,500 1 16.19 4.750 1.250 1 11.54 4,500 1.250 1 3,59 4.750 1,250 1 8,53 4.700 1.250 1 24.51 4,730 1.250 1 10,86 4,730 1.250 1 10.99 4.700 2.250 1 1.45 4,563 2.250 1 5.43 4,750 2.250 1 31,07 4.563 2,250 1 30.85 4.563 2.250 1 31,03 4,563 2.250 1 2.64 4,870 2.500 3 92,04 4,000 2,563 1 32.46 4,750 2.000 2 61,33 4,000 2,563 WELL NAME REPT NO, I DATE 12 4/1/2005 I CUM, TANGO CUM INTANG WI MUD o CUM COST WI MUD 2,199,292 AUTH. FMF-3641 Geo Pilot Geo Pony Flex I-L-S IBS OM HOC SlimPhase 4 PWD TM HOC Sub - NM Float Stabilizer - Non Mag Flex Joint - Non Mag Flex Joint - Non Mag Flex Joint - Non Mag Crossover Drill Pipe - Heavy Wgt Jars - Up/Down Jars Drill Pipe - Heavy Wgt B~~/RUN31 SIZE I MANUF. 6.125 Sec/DBS BITS I TYPE I SERIAL N°'1 FMF3641 10638484 JETS OR TFA 15/15/15111 I DEPTH IN DATE IN I I-O·D-L-B-G-O·R 11 ,085.0 4/1/200~ 1-2-CT-G-D-I-EC-TD BIT I RUN WOB RPM BIT OPERATIONS GPM I PRESS I P BIT I HRS I 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP FROM 00:00 02:00 HOURS 2.00 CODE CASE P TROUBLE SUB RUNC OPERATIONS SUMMARY PHASE INTRM1 DESCRIPTION Continue running 7" casing fl 9169' to 10,737' (252 jts, total) took wieght @ 10,747' (10' in on jl.# 253) Establish circulation - 5 BPM @ 800 psi - wash down casing f/10,747' to 11,038' (last 7 jts. - ran 259 jts, total) - PU landing jl. & casing hanger - Land 7" casing on FMC fluted hanger in wellhead wI shoe @ 11,075' & Float collar @ 10,985' LD fill up tool - Blow down TD- MU cement head & lines 02:00 04:30 2,50 CASE P RUNC INTRM1 04:30 05:00 0,50 CASE P RURD INTRM1 Printed: 1/11/2006 11 :07:12 AM . . 2 of 2 CD3-108 ConocoPhiHips Alias¡ka,lnc. Daily Drilling Report I JOB NUMBER I EVEONTDCRoDE 124 HRS PROG I TMD I TVD 11,085.0 6,999.0 IDFS 10,20 I REPT NO. 12 [DATE 4/1/2005 WELL NAME OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION 05:00 06:00 1.00 CEMENT P CIRC INTRM1 Establish circulation - stage pumps up to 6 BPM @ 720 psi - Circulate & condition for cement job - P JSM 06:00 06:30 0,50 CEMENT P PUMP INTRM1 Cement 7" casing as follows: Pumped 5 bbl CW-100 - Test lines to 3700 psi - pump 15 bbls CW-100 @ 4 B/P @ 480 psi - Drop btm plug - Mix & pump 30 bbls MudPush XL @ 12,5 ppg - 4 B/M @ 500 psi - Mix & pump 52 bbl Lead slurry (Class G wI ,2% 0046, ,3% 0065, .07% B155, .4% 0167) @ 15,8 ppg - 5.4 B/M @ 500 psi 06:30 08:00 1.50 CEMENT P DISP INTRM1 Drop top plug - Pumped 20 bbls water wI Dowell - Switch to rig pumps & displaced wI 398,5 bbls 10,0 ppg mud @ 6,2 B/M @ 480 to 780 psi - slowed rate to 3.5 B/M for last 18.5 bbls - 550 to 640 psi - bumped plug w/11 00 psi - check floats - OK - CIP @ 0747 hrs. Full returns throughout job 08:00 09:00 1,00 CEMENT P OTHR INTRM1 Pressure test csg to 3500 psi for 30 mins. - Blow down lines - RD cmt equipment 09:00 09:30 0.50 DRILL P PULD INTRM1 LD landing jt. - pull thin wall wear bushing 09:30 10:30 1,00 DRILL P PULD INTRM1 Install pack off & test to 5000 psi for 10 mins. - LD csg equipment 10:30 12:00 1.50 WELCTL P EQRP INTRM1 Install test plug - change top pipe rams to 3 1/2" x 6" VBR 12:00 17:30 5,50 WELCTL P BOPE INTRM1 RU & test BOPE to 250 psi low & 5000 psi high, Hydril to 250 psi low & 3500 psi high, Test waived by AOGCC by Jeff Jones, Install wear bushing, Blow down Choke & Kill lines. 17:30 18:30 1,00 DRILL P PULD INTRM1 Install Bails, Elevators, Clean rig floor. 18:30 21:00 2.50 DRILL P PULD INTRM1 Pick up 4" drill pipe from pipe shed to 1900', POOH & stand back in derrick. 21:00 00:00 3,00 DRILL P PULD INTRM1 Make up 6-1/8" Bit, 4-3/4" Geo-Pilot & BHA #3, Program tools, 24 HR SUMMARY: Run 7" csg to 11075', Circ & Cond mud f/ cmt, Cmt 7" csg wI 52.4 bbls cmt- Bump plug, Install pack off, Test BOPE, M/U BHA & RIH wI 4" DP. COMPANY ConocoPhillips Company Fairweather E&P Service Doyon Drilling Inc ACI - Arctic Catering Halliburton - Sperry-Sun Halliburton - Sperry-Sun SERVICE PERSONNELDATA NO. HOURS COMPANY M-I Drilling Fluids 2 Swaco 25 Dowell 5 Alaska Clean Seas 2 Epoch Well Services Inc 2 FMC Corporation Well he HOURS 2 4 3 2 2 ITEM Fuel Rig Water, Drilling UNITS gals bbls USAGE 3,369 MATERIALS 1 CONSUMPTION ON HAND ITEM 12,574 Water, Potable 600 Camp fuel UNITS bbls gals USAGE ON HAND 1,120 RESERVOIR NAME CD1-19A I CD3-1 08 RESERVOIR AND INTERVALDATA ZONE I TOP I BASE I 1925 0 COMMENTS Printed: 1/11/2006 11 :07:12 AM ~- ~~ ~---~----::---~-------------------------.I PRESSURE INTEGRITY TEST CONOCOPHllllPS Alaska, Ine. Wel! Name: I Ri9: Date: Drilling Supervisor: I Cement Unit Type of Test: Annulus Leak Off Test for Disposal Adequacy ... r Pumping dOW~ annulus. Hole Size: 18-1/2" ...., Casing Shoe Depth I I Hole Depth RKB..cHF: _OFt-TVD _OFt-TVD Casinq Size and Description: 19-5/8" 36#/Ft J-55 BTC I.... r Chanqes for Annular Adequacy Test Pressure InteqrityTest Enter outer casing shoe test results in comments Mud Weight ppg Casing description references outer casing string. Inner casing 00: In. Hole Size is that drilled below outer casing. Use estimated TOC for Hole Depth. Enter inner casing 00 at right. Volume Input Pump Rate: ... ..... Bbls/Strk ..... Barrels .... Bbl/min ... Casing Test Pumping Shut-in Bbls Min psi o 1 2 3 4 5 6 7 8 9 10 15 20 25 30 Pressure Integrity Test Pumping Shut-in Bbls Min psi 0.00 0.25 0.50 1.00 1.50 2.00 2.50 3.00 3.50 4.00 4.50 5.00 5.50 6.00 6.50 7.00 7.50 8.00 8.50 9.00 9.50 10.00 Desired PIT EMW: Estimates for Test: ppg 632 psi 0.6 bbls T~ -.-., EMW = leak..off Pressure + Mud Weight = 875 0.052 x TVD 0.052 x 2431 + 10 EMWat 3074 Ft-MD (2431 Ft-TVD):::: 16.9 PIT 15 Second Shut-in Pressure, psi 742 1000 ------...". ~-~~ /- / I: W 0::: :) W 500 W W 0::: Il. ~-",. o o 2 4 6 Barrels B 10 12051015202530 Shut-In time, Minutes o PIT Point Volume Pumped 0.0 Bbls Volume Bled Back Volume Pumped 11.0 Bbls Volume Bled Back ---CASING TEST _LEAK-OFF TEST Comments: , ( t;U::S-l Uti Annular LV I Summary . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 ütt dD5- Û ')?J February 16, 2006 1 ~-74-1if RE: MWD Fonnation Evaluation Logs CD3-108, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 CD3-108: LAS Data & Digital Log Images: 50-103-20507-00 1 CD Rom ~LL }/ (#I~ . Conoc6Phillips . G. C. Alvord Alpine Drilling Team Leader Drilling & Wells p, O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 June 16, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for CD3-1 08 (#205-033) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Alpine well CD3-1 08. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, ¡Q, f. ()Z G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad .. STATE OF ALASKA I ALASKA Oil AND GAS CONSERVATION COMMION WELL COMPLETION OR RECOMPLETION REPORT AND LOG WAG ø' 1 b, Well Class: "6~. . vi Development 0 Exploratory 0 ~ ~ Service 0 Stratigraphic TesD 12, Permit to Drill Number: 1a, Well Status: Oil 0 Gas U JP!dSPL 0 GINJ 0 WlNJ r 2, Operator Name: Plugged 0 Abandoned 0 20AAC 25,105 No, of Completions _ ConocoPhillips Alaska, Inc, 3, Address: p, O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 1349' FSL, 816' FEL, Sec. 5, T12N, R5E, UM At Top Productive Horizon: 2331' FSL, 724' FWL, Sec. 33, T13N, R5E, UM Total Depth: 1586' FNL, 1806' FWL, Sec, 29, T13N, R5E, UM 4b, Location of Well (State Base Plane Coordinates): Surface: x- 388228 J Y- TPI: x- 392484 y- Total Depth: x- 388364 .. y- 18, Directional Survey: Yes 0 NoU 21, Logs Run: GRlRes, Dens/Neutron 22. CASING SIZE wr, PER FT, 16" 62,5# 9,625" 36# 7" 26# GRADE H-40 J-55 L-80 I 6003843 6010042 6016746 ~ Zone- 4 Zone-4 Zone- 4 Suspended 0 20AAC 25,110 Other 5, Date Comp., Susp" or Aband,: 6, Date Spudded: March 22, 2005 7, Date TD Reached: April 9, 2005 / 8, KB Elevation (ft): 36,7' RKB 149,6' AMSL 9, Plug Back Depth (MD + TVD): 18915' MD 16816' TVD 10, Total Depth (MD + TVD): "18915'MD/6816'TVD .. April 11 ,2005 " 11, Depth where SSSV set: landing nipple @ 2267' 19, Water Depth, if Offshore: N/A feet MSL CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM 36,7' 114' 36.7' 114' 36,7' 3075' 36.7' 2437' 36,7' 11076' 36.7' 6998' 23, Perforations open to Production (MD + TVD ofTop and Bottom Interval, Size and Number; if none, state "none"): open hole completion 26, Date First Production Date of Test Hours Tested Flow Tubing Casing Pressure press, psi 27. HOLE SIZE 12,25" 8,5" 24, SIZE 4.5" 205-033 / 13. API Number: 50-103-20507-00 14. Well Name and Number: CD3-108 15, Field/Pool(s): Colville River Field Fiord Oil Pool 16, Property Designation: ADL 372105/372104/364471 17, Land Use Permit: LAS21122 20, Thickness of Permafrost: 1293' MD CEMENTING RECORD AMOUNT PULLED 42" 10 yds Portland Type III 522 sx AS Lite, 239 sx Class G 254 sx Class G TUBING RECORD DEPTH SET (MD) 10097' I PACKER SET 10037' 25, ACID, FRACTURE, CEMENT SQUEEZE, ETC, DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED GAS-MCF WATER-BBL n/a CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary), Submit core chips: if none, state "none", -~-----\ GOMPLE1WN ¡ MTE I ~ .¡, /1-ðÇ i i 'FE;\! W:n ! t~~:,·;J RBDMS 8Ft. JUN 2 0 2005 Form 10-407 Revised 12/2003 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc,) Shut-In, refer to attachment for flowback rates Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE Test Period --> Calculated OIL-BBL 24-Hour Rate -> NONE CONTINUED ON REVERSE IGAS-OIL RATIO OIL GRAVITY - API (corr) not available &F 28, . GEOLOGIC MARKERS 29, . FORMA nON TESTS NAME MD TVD Include and briefly summarize test results, List intervals tested, and attach detailed supporting data as necessary, If no tests were conducted, state "None", CD3-108 Seabee Form. Nanushak Gamma Ray Shale Kalubik Kuparuk Formation 3203' 5460' 9564' 10060' 10147' 2509' 3913' 6456' 6706' 6746' N/A 30, LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, Mechanical Integrity Test, Monthly Production Report 31, I hereby certify that the foregoing is true and correct to the best of my knowledge, Contact: Vern Johnson @ 265-6081 Printed Name A:) Mvord Signature / --t'.. Title: Phone Alpine DrillinQ Team Leader Date " (I' {o~ Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska, Item 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 elevation in feet abour mean low low water, Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness, Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26, (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none", Item 29: List all test information. If none, state "None", Form 10-407 Revised 12/2003 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD3-108 CD3-108 ROT - DRILLING doyon1@ppco.com Doyon 19 Start: 3/19/2005 Rig Release: 4/11/2005 Rig Number: 19 Spud Date: 3/18/2005 End: 4/11/2005 Group: 3/21/2005 08:30 - 12:00 3,50 MOVE RURD RIGUP Positioned rig over well. Rigging up while moving pipe shed and Ball , mill. 12:00 - 20:30 8,50 MOVE RURD RIGUP Continue rig up, 20:30 - 00:00 3,50 WELCTL NUND RIGUP Nipple up Diverter and connect lines. Rig accepted @ 2030 Hrs, 3/22/2005 00:00 - 05:00 5.00 WELCTL NUND RIGUP Continue hooking up Diverter. Had to pick up and turn one hole to connect lines. Pipe header support in the path of Diverter line.. 05:00 - 07:00 2,00 DRILL OTHR RIGUP Load pipe shed w/72 jts, 5" Drill pipe & 27 jts 5" HWDP, BHA. 07:00 - 08:30 1,50 DRILL PULD RIGUP Pick up Flex collars, Jars (Had to steam for rabbit) 08:30 - 09:30 1,00 DRILL OTHR RIGUP Strap 5" Drill pipe & HWDP, 09:30 - 12:00 2,50 WELCTL NUND RIGUP Nipple up riser, Install riser cover under master bushing, 12:00-15:15 3.25 DRILL PULD RIGUP Pick up & stand back 72 jts. 5" drill pipe, 15:15 - 15:45 0.50 WELCTL BOPE RIGUP Function test Diverter system, Test waived by AOGCC Chuck Schevee. 15:45 - 17:00 1,25 DRILL ·PULD RIGUP Pick up & stand back 27 jts 5" HWDP. 17:00 - 17:30 0,50 DRILL PULD SURFAC Make up 12-1/4" Bit, Motor, Stab, Float sub. 17:30 - 18:00 0.50 DRILL CIRC SURFAC Fill Conductor & Diverter system & check for leaks, Test pump lines to 3000 psi. 18:00 - 18:45 0.75 DRILL SFTY SURFAC Held Pre spud meeting & Shallow gas drill w/ all personnel. 18:45 - 19:00 0,25 DRILL CIRC SURFAC Clean out ice plug f/43' to 114'. 19:00 - 19:45 0,75 DRILL DRLG SURFAC Spud well @ 19:00 hrs 3/22/05, Drill 12-1/4" Hole f/114' to 218' ,ART= " .58 hrs, AST= 0 hrs, WOB 5/1 OK, 400 gpm @ 350 psi, RPM 50, 19:45 - 20:15 0,50 DRILL TRIP SURFAC Circ, Blow down top drive, POOH & stand back HWDP & DC's. 20: 15 - 23:30 3.25 DRILL TRIP SURFAC Pick up MWD tools, Install pulser, Program MWD tools, Install sources, , Pick up DC's, RIH to 200', Surface test MWD tools, 23:30 - 00:00 0.50 DRILL DRLG SURFAC Drill f/218' to 283' (65'), 283' TVD, ART= .45 hrs, AST= 0 hrs, WOB 10/15K, RPM 60, 455 gpm @ 950 psi, UP 100K, ON 100K, ROT 100K, Torque on 5000 ftllb - off 4500 ftllb. 3/23/2005 00:00 - 12:00 12,00 DRILL DRLG SURFAC Drill f/283' to 1591' (1308'), 1482' TVD, ART= 2.40 hrs, AST= 6,52 hrs, WOB 20/40K, RPM 40,500 gpm @ 1480 psi, UP 130K, ON 125K, ROT 130K, Torque on 7000 ftllb - off 9000 ftllb, 12:00 - 00:00 12,00 DRILL DRLG SURFAC Drill f/1591' to 3000' (1409'), 2384' TVD, ART= 4.96 hrs, AST= 1,28 hrs, WOB 30/40K, RPM 70, 635 gpm @ 2480 psi, UP 145K, ON 120K, ROT 135K, Torque on 10,000 ftllb - off 8,000 ftllb, 3/24/2005 00:00 - 01 :00 1,00 DRILL DRLG SURFAC Drill f/3000' to 3085' (85'), 2437' TVD, ART= ,77 hrs, AST= 0 hrs, WOB 30/40K, RPM 70, 635 gpm @ 2480 psi, UP 150K, ON 125K, ROT 140K, Torque on 9,000 ftllb - off 7,000 ftllb, 01 :00 - 01 :30 0,50. DRILL CIRC SURFAC Circ 2 btm's up & hole clean w/ 630 gpm @ 2150 psi & 70 RPM. 01 :30 - 05:30 4,00 DRILL WIPR SURFAC Observe well, Back ream out of hole f/ 3085' to HWDP @ 1024' w/630 to 450 gpm & 70 RPM, Pulling speed 40/45 ftlmin, Note; Slowed back reaming speed down after pulling 10 stands (Pulled total of 20 stands) to let clean up and hole cleaned up fine - Slowed rate down again on last 2 stands to let hole clean up, But hole would not clean up- Had excess sand over shakers. 05:30 - 07:00 1,50 DRILL WIPR SURFAC RIH f/1024' to 3019' (Hole in good shape), Precautionary wash & ream f/3019' to 3085'. 07:00 - 08:30 1.50 DRILL CIRC SURFAC Circ hole clean w/ 3 time btm's up ar rate of 650 gpm @ 2020 psi & 70 RPM, Observed well- OK. 08:30 - 12:00 3,50 DRILL TRIP SURFAC POOH on elevators to BHA (Hole in good shape), Observed well 12:00 - 15:30 3,50 DRILL PULD SURFAC Stand back DC's, PJSM, Remove RA Sources, Down load MWD tools, Lay down Pulser sub, MWD tools, Break bit & lay down motor, Clear rig floor. 15:30 - 17:00 1.50 CASE RURD SURFAC Rig to run 9-5/8" casing, PJSM w/ all personnel. 17:00 - 19:45 2.75 CASE RUNC SURFAC Make up & Thread lock 9-5/8" Silver bullet float shoe, 2- jts 9-518", 36#, Printed: 4/26/2005 1 :06:51 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD3-108 CD3-108 ROT - DRILLING doyon 1 @ppco.com Doyon 19 Start: 3/19/2005 Rig Release: 4/11/2005 Rig Number: 19 Spud Date: 3/18/2005 End: 4/11/2005 Group: 3/24/2005 17:00 - 19:45 2,75 CASE RUNC SURFAC J-55, BTC csg, 9-5/8" Float collar, Circ & check float equip., RIH to 1477', 19:45 - 20:15 0,50 CASE CIRC SURFAC Circ csg vol., Stage rate up f/2 bpm to 4 bpm @ 220 psi, UP 125K, ON 112K, Full returns, 20:15 - 22:30 2.25 CASE RUNC SURFAC Continue running 9-5/8" csg, to 3035', Make up FMC Gen V Casing hanger & Landing jt., Land csg @ 3075'. 22:30 - 22:45 0.25 CEMENT PULD SURFAC Lay down Frank's fill up tool, Make up Dowell cement head. 22:45 - 00:00 1,25 CEMENTCIRC SURFAC Circ & condo mud for cement, Stage rate up f/ 2 bpm @ 300 psi to 5 bpm @ 310 psi, UP 160K, ON 130K, 3/25/2005 00:00 - 01 :00 1,00 CEMENT CIRC SURFAC Circ & cond, mud for cement, Stage rate up f/5 bpm @ 310 psi to 6 bpm @ 250, Reciprocate casing 20', UP 160K, ON 137K. 01 :00 - 03:30 2,50 CEMENT PUMP SURFAC Held PJSM w/ all personnel, Pump 40 bbls biozan water w/ nut plug at rate of 6.0 bpm @ 240 psi with rig pump, Swith to Dowell & pump 3 bbls water, Test lines to 3000 psi, Drop btm plug, Mix & pump 50 bbls 10.5 ppg MudPUSH XL at rate of 5.0 bpm @ 175 psi, Mixed & pumped 414 bbls (522 sxs) 10.7 ppg Lead slurry plus additives at rate of 7,5 bpm @ 50 to 350 psi, Observed nut plug at shakers after pumping 357 bbls lead, Stopped reciprocating casing after pumping 319 bbls lead (82 bbls lead around shoe) due to decrease in down weight, Switched to Tail & pumped 50 bbls (239 sxs) plus additives at 15,8 ppg at rate of 5.2 bpm @ 465 to 515 psi, Shut down & drop top plug, Displace plugs w/20 bbls fresh water, Switch to rig pumps & displace w/ total of 213.8 bbls 9.6 ppg mud at rate of 7.0 bpm @ 420 to 770 psi, Slowed rate down to 3 bpm @ 560 psi on last 13 bbls, Bumped plug w/1 060 psi, C,I.P @ 03:30 hrs 3/25/05, Floats held OK, Had full returns thru out job w/213 bbls good cmt returns to surface. .... 03:30 - 04:15 0.75 CASE MIT SURFAC Rig & test 9-5/8" casing to 2500 psi for 30 min. 04: 15 - 06:00 1,75 CEMENTPULD SURFAC Rig down Dowell cement head, Lay down landing joint, Flush out cmt f/ diverter& riser. 06:00 - 09:30 3.50 WELCTL NUND SURFAC Nipple down diverter system, 09:30 - 13:30 4,00 WELCTL OTHR SURFAC Resurvey conductor for wellhead alingment. 13:30 - 16:15 2,75 WELCTL NUND SURFAC Install & test FMC Gen, Wellhead, Install & nipple up BOPE. 16:15 - 22:30 6.25 WELCTL BOPE SURFAC Rig & Test Hydrill to 250 psi low & 3500 psi high, All other BOPE equip. to 250 psi low & 5000 psi high, Lay down test joint, Install wear bushing, 22:30 - 00:00 1.50 DRILL PULD SURFAC Pick up short bails & elevators, Pick up 4" drill pipe from pipe shed. 3/26/2005 00:00 - 02:00 2,00 DRILL PULD SURFAC Pick up 4" drill pipe from pipe shed to 2860', Circ btm's up at rate of 500 gpm @ 1020 psi. 02:00 - 03:30 1,50 DRILL TRIP SURFAC I POOH & stand back 30 stands in derrick, 03:30 - 06:30 3.00 DRILL PULD SURFAC Pick up 4" drill pipe form pipe shed nto 2955', Circ pipe volume. 06:30 - 08:00 1,50 DRILL TRIP SURFAC ,POOH & stand back 31 stands in derrick. 08:00 - 11 :00 3.00 DRILL PULD SURFAC Pick up 4" drill pipe form pipe shed nto 2955', Circ pipe volume. 11 :00 - 12:00 1.00 DRILL TRIP SURFAC POOH & stand back 31 stands in derrick, 12:00 - 15:45 3,75 DRILL PULD SURFAC Make up 8-1/2" Bit, 6-3/4" Geo Pilot, Pony collar, MWD tools, Float sub, Load MWD, Test Geo span unit to 4500 psi, Pulse test down link to Geo Pilot, Load RA Sourses, Pick up Flex DC's. 15:45 - 17:15 1.50 DRILL TRIP SURFAC RIH w/ HWDP, Jars, Ghost reamers, 5" drill pipe & tag cmt stringer @ 2928'. 17:15 - 18:00 0.75 DRILL CIRC SURFAC Break circ, Wash to 2935', Circ btm's up at rate of 500 gpm @ 1470 psi & 50 RPM, Blow down top drive, 18:00 - 19:00 1,00 RIGMNT RSRV ,SURFAC PJSM, Cut & Slip drilling line. 19:00-19:15 0.25 DRILL REAM SURFAC Wash & ream out firm cement f/ 2935' to 2990' at rate of 450 gpm @ 1280 psi w/60 RPM, 19:15 - 20:45 1,50 DRILL OTHR SURFAC I Drill out float collar @ 2990', Shoe track to 3031', Printed: 4/26/2005 1 :06:51 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD3-108 CD3-108 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: 3/19/2005 Rig Release: 4/11/2005 Rig Number: 19 Spud Date: 3/18/2005 End: 4/11/2005 Group: 3/26/2005 20:45 - 21 :15 0.50 RIGMNT RGRP SURFAC Change out High & Low Drum clutch on drill console, 21:15-22:00 0,75 DRILL OTHR SURFAC Finish drilling out shoe track & shoe @ 3075', Drill out rathole to 3085'. 22:00 - 22:30 0.50 DRILL DRLG SURFAC Drill 20' new hole to 3105', 2449' TVD, ART= .3 hrs, 22:30 - 23:15 0.75 DRILL CIRC SURFAC Circ hole clean for LOT w/3 times btm's up at rate of 550 gpm @ 1760 psi & 120 RPM. 23:15 - 00:00 0,75 DRILL LOT SURFAC Blow down top drive, Rig & Preform LOT w/956 psi, 2431' TVD, 9,5 ppg mud = 17.1 ppg EMW. .... 3/27/2005 00:00 - 00:30 0.50 DRILL RIRD INTRM1 Rig down LOT lines, Blow down lines, Displace to 9,8 ppg LSND mud. 00:30 - 12:00 11.50 DRILL DRLG INTRM1 Drill f/3105' to 4462' MD /3279' TVD (1357'), ADT= 7.22 hrs, WOB 8/15K, RPM 150, 625 gpm @ 2480 psi, UP 165K, ON 115K, ROT 130K, Torque on 11,000 ftllb - off 10,500 ftllb, ECD's ranging f/11.4 to 12.0 ppg, Mud wt, 9,8 ppg, Pumping Hi-vis weighted sweeps every 3 stands. 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drill f/4,462' to 5,798' MD 14,129' TVD (1,336'), ADT= 7,48 hrs, WOB I 10/20K, RPM 155, 625 gpm @ 3300 psi, UP 186K, ON 124K, ROT 145K, Torque on 11,000 ftllb - off 10,200 ftllb, ECD's ranging f/11,7 to 12.3 ppg, Mud wt, 9.8 ppg, Pumping Hi-vis weighted sweeps every 3 stands, 3/28/2005 00:00 - 12:00 12,00 DRILL DRLG INTRM1 Drill f/ 5,798' to 7,305' MD / 5,069' TVD (1,507'), ADT= 8.45 hrs, WOB 16/23K, RPM 155, 625 gpm @ 3300 psi, UP 213K, ON 130K, ROT 155K, Torque on 12,000 ftllb - off 10,500 ftllb, ECD's ranging f/11,3 to 11,6 ppg, Mud wt, 9,8 ppg, Pumping Hi-vis weighted sweeps every +/- 10 stands. 12:00 - 00:00 12,00 DRILL DRLG INTRM1 Drill f/7,305' to 8,900' MD /6,061' TVD (1,595'), ADT= 7,55 hrs, WOB 15/24K, RPM 165, 637 gpm @ 3700 psi, UP 230K, ON 145K, ROT 176K, Torque on 14,500 ftllb - off 13,000 ftllb, ECD's ranging f/11,3 to 11,6 ppg, Mud wt. 9,8 ppg, Pumping Hi-vis weighted sweeps every +/- 10 stands. 3/29/2005 00:00 - 12:00 12,00 DRILL DRLG INTRM1 Drill 8 1/2" hole w/ Geo Pilot f/ 8900' to 10,170' MD 6754' TVD ADT - 8.15 hrs WOB 17/22 k RPM 155 GPM 600 @ 3880 psi String wt, PU 205 SO 155 Rot 175 Torque on/off btm - 12,500/9,500 fj, Ibs. ECD - 11.1 to 11.6 ppg, 12:00 - 23:15 11.25 DRILL DRLG INTRM1 Drill f/1 0, 170' to 11,085' MD /6,999' TVD (915'), ADT= 7.65 hrs, WOB 10/22K, RPM 150, 590 gpm @ 3940 psi, UP 215K, ON 150K, ROT 180K, Torque on 14,500 ftllb - off 12,000 ftllb, ECD's ranging f/11,1 to 11.6 ppg, Mud wt, 9,8 ppg, Very little cuttings increase on Hi-vis weighted sweeps, 23:15 - 00:00 0,75 DRILL CIRC INTRM1 Pump Hi-vis sweep & circ hole clean, 3/30/2005 00:00 - 01 :30 1,50 DRILL CIRC INTRM1 Circ & condition for wiper trip - 3X btms up - 592 gpm @ 3950 psi w/ 100 rpm - Std back 2 stds to 10,888' 01 :30 - 04:30 3,00 DRILL WIPR INTRM1 Flow check (static) POOH wI pump f/10,888' to 9170' @ 460 gpm @ 2500 psi w/1 00 rpm - flow check ( static) 04:30 - 05:30 1,00 DRILL TRIP INTRM1 RIH f/9170' to 10,983' 05:30 - 06:00 0,50 DRILL REAM INTRM1 Wash down f/1 0,983' to 11,085' Pump hi vis sweep(std back 1 std) 06:00 - 07:30 1,50 DRILL CIRC INTRM1 Circ & condition - 2X btms up - 592 gpm @ 3940 psi w/160 rpm 07:30 - 10:00 2.50 DRILL WIPR INTRM1 Flow check(static) POOH w/ pump f/10,888' to 9170' @ 460 gpm @ 2400 psi w/1 00 rpm 10:00 - 11 :00 1.00 DRILL TRIP INTRM1 Flow check(static) RIH w/ 9170' to 10,983' 11 :00 - 12:00 1,00 DRILL REAM INTRM1 Wash down f/1 0,983' to 11,085' - Pump hi vis sweep 12:00 - 12:45 0,75 DRILL CIRC INTRM1 Circ out sweep at rate of 575 gpm @ 3960 psi w/160 RPM, Spot lubrication pill for 7" casing, Printed: 4/26/2005 1 :06:51 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD3-108 CD3-108 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: 3/19/2005 Rig Release: 4/11/2005 Rig Number: 19 Spud Date: 3/18/2005 End: 4/11/2005 Group: 3/30/2005 12:45 - 13:00 0,25 DRILL TRIP INTRM1 Attempt to POOH while spotting pill on btm at 3 bpm - No good (Pill 9.6 ppg and out of balance). 13:00 - 15:45 2,75 DRILL CIRC INTRM1 I Circ out pill and capture same in pill pit, Stand back 1 stand to 10,856' while circ, Recondition pill and weight up to 10.0 ppg, RIH to 11,047', Spot pill. 15:45 - 18:15 2,50 DRILL CIRC INTRM1 POOH to 9,138' while spotting pill at rate of 3 bpm @ 460 psi, Flow check well- OK. 18:15 - 19:15 1,00 DRILL TRIP INTRM1 POOH 10 stands on elevators and check hole fill- OK, Monitor well. 19:15 - 19:30 0.25 DRILL CIRC INTRM1 Pump dry job & Blow down top drive, 119:30 - 00:00 4,50 DRILL TRIP INTRM1 POOH on elevators to 5" drill pipe @ 2,838' (Hole in very good shape), Change out to 5" equipment, POOH & lay down Ghost reamer to 1756'. 3/31/2005 .00:00 - 01 :30 I 1,50 DRILL TRIP INTRM1 Continue POOH on TT f/1756' to 730' - flow check(static) Std back HWDP & LD jars 01 :30 - 05:00 I 3.50 DRILL PULD INTRM1 Flow check (static) Std back NM flex DC's - remove RA sources fl MWD - down loads MWD - service Geo Pilot - LD MWD, Geo Pilot, & bit 05:00 - 05:30 0,50 DRILL 10THR INTRM1 Pull wear bushing 05:30 - 09:30 4,00 CASE RURD INTRM1 Set test plug - Change top pipe rams to 7" & test - Set thin wall wear bushing - RU 09:30 - 11 :00 1,50 CASE RUNC INTRM1 PJSM - Ran 7" 26# L-80 MBTC as follows: Float shoe (Ray Oil tool I Silver bullet) 2 jts, - float collar( Weatherford) 2 jts,( first 4 connections 111 :00 - 13:45 made up w/ BakerLoc) filled pipe & checked floats 2,75 CASE 'RUNC INTRM1 Continue to run 7" 26# L-80 MBTC casing f/173' to 3074' (72 jts, total) 13:45-14:151 0.50 CASE CIRC INTRM1 Break circulation - circulate casing volume @ 5 BPM @ 360 psi - PU wt 130 SO wt, 120 ( packer cup leaking while circulating) 14:15 - 15:30 1,25 CASE OTHR INTRM1 Change out Frank's fill up tool 15:30 - 18:30 3.00 CASE RUNC INTRM1 [Continue to run 7" casing f/3074' to 6388'. 18:30 - 19:30 1,00 CASE CIRC INTRM1 Circ btm's up @ 6388', Stage pump rate up f/2,5 bpm to 5.0 bpm @ 490 psi, Good returns, UP 195K, ON 145K, 19:30 - 22:30 3.00 CASE RUNC INTRM1 Continue to run 7" casing f/6388' to 9126'. 22:30 - 00:00 1,50 CASE CIRC INTRM1 Circ btm's up @ 9126', Stage pump rate up f/2.5 bpm @ 680 to 5,0 I bpm @ 640 psi, Good returns, Picked up 1 joint to 9169' after 45 min" UP 240K, ON 160K, 4/1/2005 00:00 - 02:00 2.00 CASE RUNC INTRM1 Continue running 7" casing f/ 9169' to 10,737' (252 jts, total) took wieght @ 10,747' (10' in on jt.# 253) 02:00 - 04:30 2,50 CASE RUNC INTRM1 Establish circulation - 5 BPM @ 800 psi - wash down casing f/10,747' I to 11,038' (last 7 jts, - ran 259 jts, total) - PU landing jt. & casing hanger ! - Land 7" casing on FMC fluted hanger in wellhead w/ shoe @ 11,075' & Float collar @ 10,985' 04:30 - 05:00 0,50 CASE rURD INTRM1 LD fill up tool - Blow down TD- MU cement head & lines 05:00 - 06:00 1,00 CEMEN CIRC INTRM1 Establish circulation - stage pumps up to 6 BPM @ 720 psi - Circulate & condition for cement job - PJSM 06:00 - 06:30 0.50 CEMEN PUMP INTRM1 Cement 7" casing as follows: Pumped 5 bbl CW-100 - Test lines to I 3700 psi - pump 15 bbls CW-100 @ 4 B/P @ 480 psi - Drop btm plug- Mix & pump 30 bbls MudPush XL @ 12.5 ppg - 4 B/M @ 500 psi - Mix & pump 52 bbl Lead slurry ( Class G w/ .2% 0046, .3% 0065, ,07% B155, .4% 0167) @ 15,8 ppg - 5.4 B/M @ 500 psi 06:30 - 08:00 1.50 CEMENT DISP INTRM1 I Drop top plug - Pumped 20 bbls water wI Dowell - Switch to rig pumps I & displaced w/398,5 bbls 10,0 ppg mud @ 6.2 B/M @ 480 to 780 psi - slowed rate to 3,5 B/M for last 18,5 bbls - 550 to 640 psi - bumped plug w/1100 psi - check floats - OK - CIP @ 0747 hrs, Full returns CEMENTOTHR IINTRM1 throughout job 08:00 - 09:00 1,00 Pressure test csg to 3500 psi for 30 mins, - Blow down lines - RD cmt I I I Printed: 4/2612005 1 :06:51 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD3-108 CD3-108 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: 3/19/2005 Rig Release: 4/11/2005 Rig Number: 19 Spud Date: 3/18/2005 End: 4/11/2005 Group: 08:00 - 09:00 1.00 CEMENTOTHR 09:00 - 09:30 0.50 DRILL PULD 109:30 - 10:30 1,00 DRILL PULD 10:30 - 12:00 1.50 WELCTL EQRP INTRM1 12:00 -17:30 5,50 WELCTi BOPE INTRM1 17:30 - 18:30 1.00 DRILL PULD IINTRM1 18:30-21:00 2,50 DRILL PULD INTRM1 21 :00 - 00:00 3,00 DRILL PULD INTRM1 4/2/2005 00:00 - 00:30 0,50 DRILL OTHR INTRM1 00:30 - 01 :30 1,00 DRILL PULD IINTRM1 01 :30 - 04:00 2.50 DRILL PULD INTRM1 '04:00 - 04:30 I 0,50 DRILL OTHR INTRM1 04:30 - 10:00 5.50 DRILL TRIP INTRM1 10:00 - 10:30 0.50 DRILL TRIP INTRM1 10:30 - 12:00 1.50 DRILL CIRC INTRM1 12:00 - 13:30 1.50 RIGMNT RSRV INTRM1 13:30 - 14:30 1,00 DRILL REAM INTRM1 14:30 - 17:30 3.00 CEMENTDSHO INTRM1 17:30 - 18:00 0.50 DRILL DRLG INTRM1 18:00 - 19:30 1,50 DRILL ¡CIRC INTRM1 19:30 - 20:30 1,00 DRILL FIT INTRM1 20:30 - 22:30 2.00 DRILL CIRC INTRM1 22:30 - 00:00 1.50 DRILL DRLH INTRM1 4/3/2005 00:00 - 12:00 12.00 DRILL DRLH PROD 12:00 - 00:00 equipment LD landing jt. - pull thin wall wear bushing Install pack off & test to 5000 psi for 10 mins, - LD csg equipment Install test plug - change top pipe rams to 3 1/2" x 6" VBR RU & test BOPE to 250 psi low & 5000 psi high, Hydril to 250 psi low & 3500 psi high, Test waived by AOGCC by Jeff Jones, Install wear bushing, Blow down Choke & Kill lines. Install Bails, Elevators, Clean rig floor, Pick up 4" drill pipe from pipe shed to 1900', POOH & stand back in derrick. Make up 6-1/8" Bit, 4-3/4" Geo-Pilot & BHA #3, Program tools. RU & test Geo-span to 4000 psi Shallow test MWD - Blow down TO - Cont. PU BHA #3 PU 4" HWDP & jars - RIH picking up 4" DP fl pipe shed to 2280' - filled pipe @ 2000' Fill pipe - break in bearing on GeoPilot - check MWD - blow down TO Continue RIH f/ 2880' to 9438' - picking up 4" DP f/ pipe shed Cont. RIH f/9438' to 10,775' (running stds f/ derrick) CBU @ 10,775' @ 200 gpm @ 1460 psi Service TO - Slip & cut 60' drill line Wash down f/10,775' to 10932' (tag top of cmt.) Clean out cmt f/1 0,932' to 10,984' - drill up wiper plugs & FC @ 10,985' - Clean out cmt f/1 0,986' to 11,073' - Drill out shoe f/11 ,073 to 11,075' - Clean out cmtf/11 ,075' to 11,085', Drill 20' new hole f/11,085' to 11,105' MD / 7,000 TVD, ADT= ,25hrs, 200 gpm @ 1600 psi, 70 RPM, WOB 5/8K, Mud weight 10.0 ppg, ECD's 10.8 ppg, Circ btm's up & hole clean for F.I.T" Observe well- Static. Rig & Perform 12.5 ppg F.I.T. w/10,O ppg OMW, 913 psi, 6998' TVD, Change well over to 9.2 ppg Flo-Pro mud, Obtain slow pump rates, Monitor well while cleaning out under shakers- Static, Obtain clean hole ECD's of 10,2 ppg. Drill 6-1/8" hole w/ Geo-Pilot f/11,1 05' to 11,132' MD / 7001' TVD, ADT= .75 hrs, 200 gpm @ 1450 psi, WOB 5/8K, 70 rpm, UP 190K, ON 155K, ROT 175K, ECD's 10.2 ppg w/9,2 ppg mud, Drill 6 1/8" horizontal section w/ GeoPilot f/11 ,132' to 11,690' MD 7008' TVD ADT - 8.5 hrs. WOB 8/14 k RPM 110 GPM 225 @ 1870 psi String wt. PU 190 SO 155 Rot 175 Torque onloff btm. - 10,000/8,500 fj, Ibs. ECD - 10,4 to 10,8 Mud wt, 9,2+ Observed slight flow on connection @ 11,590' 12.00 DRILL DRLH PROD Drill 6 1/8" hroizontal section w/ GeoPilot f/11 ,690' to 12,312' MD / 6,989' TVD, ADT= 9.0 hrs, WOB 10/14K, RPM 110/130, 225 gpm @ 1950 psi, UP 195K, ON 150K, ROT 170K, Torque on/off- 13,000/12,500 ftllb., ECD's 10.4 to 10,8 ppg, Mud wt. 9,2+ Hole appears to be taking some fluid - observing slight flow on connections 7,00 DRILL DRLH PROD Drill 6 1/8" horizontal hole w/ GeoPilot f/12,312' to 12,870' MD 6998' TVD !WOB 10/16 k RPM 130 GPM 225 @ 1760 psi Hole taking fluid f/12,570' @ 30 to 60 BPH - losses increased to 150 BPH @ 12,870' 4/4/2005 00:00 - 07:00 Printed: 4/2612005 1 :06:51 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD3-108 CD3-108 ROT - DRILLING doyon1@ppco.com Doyon 19 Start: 3/19/2005 Rig Release: 4/11/2005 Rig Number: 19 Spud Date: 3/18/2005 End: 4/11/2005 Group: 4/4/2005 00:00 - 07:00 07:00 - 08:30 08:30 - 10:30 10:30 - 11 :00 11 :00 - 12:00 12:00 - 19:00 7,00 DRILL DRLH PROD 1.50 DRILL CIRC PROD 2.00 DRILL DRLH PROD 0,50 DRILL CIRC PROD 1,00 DRILL DRLH PROD 7.00 DRILL DRLH PROD 19:00 - 20:30 1.50 DRILL CIRC PROD 20:30 - 00:00 3,50 DRILL DRLH PROD I 4/5/2005 00:00 - 01 :30 01 :30 - 12:00 12:00 - 00:00 1,50 DRILL CIRC PROD 10,50 DRILL DRLH PROD I 12,00 DRILL DRLH PROD Wel breathing on connections Pull off btm, - slow pumps to 3.5 BPM @ 1090 psi - Circulate & add LCM to system @ 1 sxl 3 mins, Losses slowed to 80 BPH Drill 6 1/8" horizontal hole w/ GeoPilot f/12,870' to 12, 971' MD WOB 8/12 k RPM 110 GPM 186 @1450 psi Mixed & pumped LCM pill w/15 PPB Mix II fine - losses 60 to 90 BPH Well breathing on connections Circulate out LCM pill - 3.5 BPM @ 1170 psi Drill 6 1/8" horizontal hole w/ GeoPilot f/12,971' to 12,992' MD 7000' TVD ADT - 7.5 hrs since midnight WOB 8/12 k RPM 110 GPM 186 @ 1450 psi String wt. PU 200 SO 150 Rot 173 Torque onloff btm. - 12,000/10,000 ft Ibs. Well breathing on connections Hole taking fluid @ 60 to 90 BPH Observed gas & C02 on btms up after connections r- _ Lost 430 BBL mud to formation past 12 hrs. Drill 6 1/8" hroizontal section w/ GeoPilot f/12,992' to 13,353' MD / 6,990' TVD, ADT= 5.95 hrs, WOB 7/12K, RPM 110/120, 186 gpm @ 1450 psi, UP 195K, ON 145K, ROT 173K, Torque on/off- 13,500/12,500 ftIlb., ECD's 10,4 to 10,6 ppg, Mud wt, 9,2+, Hole taking 60 to 90 BPH, Maintain 2 PPB Mix II Fine & Medium while drilling, Pumped 40 PPB Safe Carb sweep, Losses increased to 200 BPH prior to sweep out of hole, Well breathing on connections, Circulate at rate of 3,0 BPM @ 1150 psi, Mix & pump 35 bbl - 15 PPB Mix II Medium & Fine LCM sweep out pipe and make connection, Losing 30 BPH while circ at 3 bpm, Drill 6 1/8" hroizontal section w/ GeoPilot f/13,353' to 13,550' MD / 6,988' TVD, ADT= 2.0 hrs, WOB 12/15K, RPM 110/120, 186 gpm @ 1580 psi, UP 195K, ON 145K, ROT 173K, Torque on/off- 13,500/12,500 ftIlb, , ECD's 10.4 to 10.6 ppg, Reduce mud wt. to 9.1 ppg, Hole taking 80 to 100 BPH, Maintain 4 PPB Mix II Fine & Medium in system while drilling, Well breathing on connections. Note: Lost 864 bbls mud in 12 hr tour / Lost 1294 bbls in 24 hrs period, Losing mud over shakers - Circulate & cond, while changing shaker screens 93 gpm @ 780 psi wI 80 rpm Drill 6 1/8" horizontal hole w/ GeoPilot f/13,550' to 14,307' MD 6963' TVD ADT - 8,05 hrs, WOB 9/12 k RPM 110/120 GPM 186 @ 1530 psi String wt. PU 210 SO 135 Rot 175 Torque onloff btm. - 14,500/12,500 ft, Ibs. Well breathing on connections Hole taking fluid @ 40-50 BPH Lost 646 bbllast 12 hrs. Observed gas & C02 on btms. up after connectioins ECD = 10,33 to 10,43 ppg Drill 6 1/8" horizontal hole wI GeoPilot f/14,307' to 15,110' MD 6952' TVD ADT- 9.38 hrs. WOB 10/17 k RPM 110/120 GPM 186 to 200 @ 1640/1760 psi String wt. PU 200 SO 130 Rot 170 Torque onloff btm, - 13,000/11,000 ft, Ibs, Printed: 4/26/2005 1 :06:51 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD3-108 CD3-108 ROT - DRILLING doyon 1 @ppco.com Doyon 19 Start: 3/19/2005 Rig Release: 4/11/2005 Rig Number: 19 Spud Date: 3/18/2005 End: 4/11/2005 Group: 4/5/2005 12:00 - 00:00 12,00 DRILL DRLH PROD Well breathing on connections Hole taking fluid @ 40 - 50 BPH Lost 316 bbls last 12 hrs. ECD = 10.33 to 10,67 ppg Total losses 2256 bbls. past 48 hrs. 4/6/2005 00:00 - 12:00 12.00 DRILL DRLH PROD Drill 6 1/8" horizontal hole w/ GeoPilot f/15, 110' to 16,000' MD 6934' TVD ADT - 9,42 hrs, WOB 10/17 k RPM 110/120 GPM 200 @ 2000 psi String wt, PU 210 SO 120 Rot 165 Torque on/off btm, - 16,000/13,000 ft, Ibs, Well breathing on connections Hole taking fluid @ 40-60 BPH Lost 580 bbllast 12 hrs, ECD = 10,9 to 11.0 ppg 12:00 - 00:00 12,00 DRILL DRLH PROD Drill 6 1/8" horizontal hole w/ GeoPilot f/16,000' to 17,060' MD 6953' TVD ADT- 9,2 hrs, WOB 10/17 k RPM 110/120 GPM 200 @ 2140 psi String wt. PU 212 SO 120 Rot 165 Torque on/off btm. - 15,000/12,000 ft. Ibs Well breathing on connections Hole taking 30 -50 BPH Lost 414 bbls last 12 hrs. ECD=10,9t011,2 ppg Lost 3,250 bbls total last 72 hrs. 4/7/2005 00:00 - 12:00 12,00 DRILL DRLH I PROD Drill 6 1/8" horizontal hole w/ GeoPilot f/17,060' to 17,450' MD 6967' TVD ADT - 9,77 hrs, WOB 10/17 k RPM 80/120 GPM 200 @ 2190 psi String wt, PU 212 SO 125 Rot 165 Torque on/off btm, - 14,500/12,500 ft, Ibs. Well breathing on connections Hole taking fluid @ 40-60 BPH Lost 468 bbllast 12 hrs, ECD = 10,8 to 10,9 ppg ** Difficulty building angle from 17361' (87,6 degree) control drill @ 20 fph from 17,361' to 17,450', 12:00 - 00:00 12,00 DRILL DRLH PROD Drill 6 1/8" horizontal hole w/GeoPilot f/17,450' to 17,915' MD 6930' TVD ADT - 10.48 hrs, WOB 8/17 k RPM 80/110 GPM 200 @ 2320 psi String wt. PU 220 SO 120 Rot 170 Torque on/off btm, - 15,500/13,000 ft. Ibs. Well breathing on connections Hole taking fluid @ 30 - 50 BPH Lost 301 bbls last 12 hrs, ECD = 10,9 to 11.1 ppg Lost 4019 bbls total last 84 hrs. 4/8/2005 00:00 - 12:00 12,00 DRILL DRLH PROD Drill 6 1/8" horizontal hole w/ GeoPilot f/17,915' to 18,495' MD 6907' TVD ADT -10,14 hrs. Printed: 4/26/2005 1:06:51 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD3-108 CD3-108 ROT - DRILLING doyon 1 @ppco,com Doyon 19 Start: 3/19/2005 Rig Release: 4/11/2005 Rig Number: 19 Spud Date: 3/18/2005 End: 4/11/2005 Group: 4/8/2005 00:00 - 12:00 12,00 DRILL DRLH PROD WOB 13/17 k RPM 110 GPM 200 @ 2440 psi String wt. PU 220 SO 110 Rot 165 Torque on/off btm, - 16,500/14,500 ft. Ibs, Well breathing on connections Hole taking fluid @ 20-30 BPH Lost 414 bbllast 12 hrs, ECD = 11.0 to 11.3 ppg 12:00 - 00:00 12,00 DRILL DRLH PROD Drill 6 1/8" horizontal hole w/ GeoPilot f/18,495' to 18,868' MD 6923' TVD ADT - 10.07 hrs, WOB 13/17 k RPM 105/120 GPM 200 @ 2400 psi String wt. PU 220 Rot 165 Torque on/off btm, - 16,000/14,000 ft, Ibs. Well breathing on connections Hole taking fluid @ 20-30 BPH Lost 414 bbllast 12 hrs, ECD = 11.0 to 11.3 ppg Lost 4,847 bbls total last 96 hrs, 4/9/2005 00:00 - 05:30 5.50 DRILL DRLH PROD Drill 6 1/8" horizontal hole w/ GeoPilot f/18,868' to 18,915' MD 6907' TVD ADT - 10,14 hrs. WOB 12/16 k RPM 115 GPM 200 @ 2090 psi String wt. PU 230 SO 120 Rot 165 Torque on/off btm. -16,000/14,000 ft, Ibs, Well breathing on connections Hole taking fluid @ 15-20 BPH ECD = 10,93 ppg 05:30 - 06:00 0.50 DRILL CIRC PROD Circ - 200 gpm /2000 psi /120 rpm 06:00 - 08:30 2,50 DRILL WIPR PROD Wipe hole from 18915' to 18,029' - 193 gpm /1940 psi /100 rpm - Monitor well, well breathing, RIH to 18, 793' - no problems 08:30 - 11 :00 2,50 DRILL CIRC PROD CBU - 200 gpm /2120 psi /110 rpm Losses @ 25-35 bph PJSM for brine change over 11 :00 - 14:00 3.00 DRILL CIRC PROD Pumped 40 bbls high vis spacer and change well over to 9.4 ppg brine 200 gpm /2100 - 1510 psi /100 rpm 16,400 - 18,300 ftllbs torque Hole taking fluid @ 20-30 bph ECD 11,2 - 10.1 ppg pumped 40 bbllcm pill during change over - displaced pill to top of open hole. 14:00 -18:00 4,00 DRILL TRIP PROD Flow check - well breathing - POOH on TT f/18, 793' to 15,357' - well breathing to 17,743' - Flow check well static - well started taking fluid f/ 17,743' - monitor well @ 16,789' - fluid level dropping in annulus - static losses 4 BPH 18:00 - 19:30 1.50 DRILL TRIP PROD Continue to POOH on TT - making MADD pass w/ MWD tools f/15,357' to 14,810' - pulling @ 450 ftlhr. - Pulled to 14,403' - Hole took 10 bbls over calc. hole fill - Monitor well fluid level dropping in annulus 19:30 - 23:00 3.50 DRILL TRIP PROD Continue to POOH on TT f/14,403' to 11,063' - hole took approx, 50% excess fill over calc, Printed: 4/2612005 1 :06:51 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD3-108 CD3-108 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: 3/19/2005 Rig Release: 4/11/2005 Rig Number: 19 Spud Date: 3/18/2005 End: 4/11/2005 Group: 4/9/2005 23:00 - 23:15 0.25 DRILL OBSV PROD Monitor well on TT - static losses 8 BPH 23: 15 - 00:00 0.75 DRILL TRIP PROD Continue to POOH on TT laying down 4" DP to 10,871' 4/10/2005 00:00 - 08:45 8,75 DRILL TRIP PROD POOH from 10871' to 375' laying down 4" drill pipe. Losses to hole @ 6-8 bph, 08:45 - 11 :30 2,75 DRILL PULD PROD LD HWDP & NM flex DC's - Down load LWD and service check GeoPilot - LD MWD & GeoPilot - clear tools from rig floor. 11 :30 -12:15 0.75 CMPLTN RURD CMPL TN Pull wear bushing - Rig up to run Completion 12:15 - 12:30 0,25 CMPL TN SFTY CMPL TN Pre-job safety and Opts meeting with crew, 12:30 - 22:00 9,50 CMPL TN RUNT CMPL TN Ran 41/2" completion as follows: WLEG - 41/2" 12.6# L-80 IBTM pup jt - 41/2" XN nipple - 1 jt 41/2" 12.6# L-80 IBTM tbg - 41/2" 12.6# L-80 IBTM pup jt. - Baker Premier packer - 4 1/2" 12,6# L-80 IBTM pup jt.(all connections below packer made up w/BakerLoc) - 2 jt. 4 1/2" 12.6# L-80 IBTM tbg - 41/2" 12.6# L-80 IBTM pup jt. - Camco GLM wI dummy valve - 41/2" 12,6# L-80 IBTM pup jt. -191 jts.4 1/2" 12.6# L-80 IBTM tbg - Camco 4 1/2" DB nipple - 56 jts. 4 1/2" 12.6# L-80 IBTM tbg. (Ran 250 jts total) 22:00 - 22:30 0,50 CMPL TN RUNT CMPL TN MU FMC tbg hanger & landing jt A - Drain BOP stack - blow down Choke, kill & fill line 22:30 - 00:00 1.50 CMPL TN RUNT CMPL TN Land tbg on FMC hanger in wellhead w/ shoe @ 10,096.7' - XN nipple @ 10084.36' - Packer @ 10,037.34' - GLM @ 9931.54' - DB nipple @ 2266,56' String wi, PU 165 SO 125 Run in lock down screws - LD landing jt. A - set TWC - MU landing jt. B - Test M toM seals on hanger to 5000 psi - LD landing jt. B Monitor tbg anmulus on TT 4/11/2005 00:00 - 03:00 3,00 CMPL TN NUND CMPL TN NO BOPE - Install adapter flange and tree - test to 5000 psi. RU lubricator and pull TWC. 03:00 - 03:30 0.50 CMPL TN NUND CMPL TN RU kill manifold and hardlines to wellhead, 03:30 - 03:45 0,25 CMPL TN SFTY CMPL TN PJSM on diesel change over 03:45 - 06:00 2,25 CMPL TN' FRZP CMPL TN Test lines to 3000 psi, displace tubing and annulus with 314 bbls of I diesel following back pressure schedule, SITP-850 psi. 06:00 - 06:30 0,50 CMPL TNI OTHR CMPL TN RU lubricator and drop ball/rod. 06:30 - 07:30 1.00 CMPL TN! OTHR CMPL TN Test lines to 5300 psi - repair leaks (drips) on two hammer unions, 07:30 - 09:15 1.75 CMPL TN! DEQT CMPL TN Test lines to 5300 psi - Set packer with 5100 psi - test tubing for 30 min. Bleed tubing to 1040 psi - test 7" x 41/2" annulus to 3500 psi bled to I 3400 psi in 30 minutes. Bleed-annulus to zero psi - bleed tubing to 875 I psi and close in wellhead valves, I 09:15 -11:30 2.25 CMPL TN! RURD CMPL TN Blow down and vac out lines - RD hardlines and manifold - RU FMC lubricator and install BPV - RD lubricator, secure and dress wellhead. 11 :30 - 14:00 2,50 CMPL TN OTHR CMPL TN Lay down excess drill pipe from derrick and clean rig floor for move. Released rig to well CD3-110 @ 1400 hours. / **Totallosses to production hole: 5007 bbls of 9.2 ppg FloPro mud and '310 bbls of 9.4 ppg kcl brine ** Printed: 4/26/2005 1 :06:51 PM . CD3-108 Well Events Summary . Date Summary 04/09/05 BEGIN RIG UP ON CD3-108 FLOW TEST 04/10105 RIG UP ON FIORD CD3-1081N PREP FOR FLOW TEST 04/11/05 CONTINUE RIG UP OF WELL TEST 04/12/05 PULLED BALL & ROD @ 10084' RKB (NOTE: FOUND ROLLER MISSING OFF OF ROD). REPLACED 1" DV @ 9932' RKB W/1" X .25" OV. PULLED 3.81" RHC PLUG BODY @ 10084' RKB, (NOTE: RECOVERED A 2.35" ROLLER IN PLUG BODY). DRIFTED 3.70" G. RING TO 10538' SLM. [GLV, Tag] 04/12/05 CONTINUE RU OF WELL TEST EQUIPMENT 04/13/05 LOG CEMENT BOND LOG FROM 10530' TO 10280'. FOUND AREA OF 75%- 85% BOND FROM 10295'-10328' AND 30% TO 50% BOND BELOW. ABOVE 10280', WELL FLUID WAS DIESÈL AND TOOL READINGS WERE NOT VALID. SBHPIT AT 10524' = 3249.9 PSI, 163.3 DEGF. WELL LEFT SHUT IN. 04/13/05 CONTINUE TO RIG UP TEST EQUIPMENT 04/14/05 EILlNE CREW WORKED ALL NIGHT AND TRAVELED BACK TO KUPARUK TODAY 04/14/05 CONTINUED RIGGING UP TEST EQUIPMENT 04/15/05 FINISHED RIGGING UP TEST EQUIPMENT. PRESSURE TESTED SYSTEM AND READY FOR FLOW TEST. 04/16/05 OPENED WELL TO TEST EQUIPMENT. USED N2 TO ASSIST IN GETTING WELL KICKED OFF. WELL CLEANED UP AND TRANSFERED INTO THE SEPERATOR. TEST IN PROGRESS. 04/17/05 WELL TEST IN PROGRESS 04/18/05 WELL TEST IN PROGRESS 04/19/05 WELL TEST IN PROGRESS 04/20105 WELL TEST IN PROGRESS. 04/21/05 WELL TEST IN PROGRESS 04/22/05 COMPLETED WELL TEST. SHUT WELL IN AND FREEZE PROTECTED TBG DOWN TO 2600' WITH 40 BBLS OF DIESEL. FLUSHED OUT LINES AND BEGIN RIG DOWN. 04/23/05 RID WELL TEST EQUIPMENT 04/24/05 RIG DOWN WELL TEST EQUIPMENT 04/25/05 WELL TEST RID & HAUL CHARGES. Inc. ConocoPhillips Alaska, Alaska North Slope North Slope, Alaska CD3-10B . Job No. AK-ZZ-3591167, SUIVeyed: 9 April, 2005 Survey Report 2005 29 April, Your Ref: 501032050700 Surface Coordinates: 6003842.60 N, 388227.68 E (70· 25'10.0077" N, 150· 54' 38.0076" Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . SUIVey Ref: svy478 W) Kelly Bushing Elevation: 51. 10ft above Mean Sea Level .pl!!..........y-.uf1 DAn_LING S&AVIC&S A HaUlburton CompalfY ConocoPhillips Alaska, Inc. Survey Report for CD3-108 Your Ref: 501032050700 Job No. AK-ZZ-3591167, Surveyed: 9 April, 2005 Alaska North Slope North Slope, Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 0,00 0.000 0.000 -51.10 0.00 O.OON 0.00 E 6003842.60 N 388227.68 E 0.00 MWD+IIFR+MS+SAG 114.00 0.000 0.000 62.90 114,00 O,OON 0,00 E 6003842.60 N 388227,68 E 0,000 0.00 194,30 0.960 27.690 143,20 194.30 0,60 N 0.31 E 6003843.19 N 388228.00 E 1.196 0.58 232.23 1.070 30.900 181.12 232,22 1.18 N 0.64 E 6003843.77 N 388228.34 E 0,326 1.15 323.19 1,610 53.080 272.06 323,16 2.68N 2.10 E 6003845.25 N 388229.82 E 0,813 2.58 413,09 2.370 48.990 361.90 413.00 4.66 N 4.51 E 6003847.19 N 388232.26 E 0.859 4.45 . 502,75 3.780 41.150 451.43 502.53 8.10 N 7,86 E 6003850,58 N 388235.66 E 1.637 7.75 590.23 5.950 45,550 538,59 589,69 13.44 N 12.99 E 6003855.85 N 388240.87 E 2.515 12.87 680.06 9.440 48.070 627.60 678.70 21.63 N 21.80 E 6003863.90 N 388249.80 E 3.902 20.66 769,50 12.250 46.820 715.43 766.53 33.03 N 34.18 E 6003875.11 N 388262.35 E 3.153 31.50 861,33 15.610 44.060 804.55 855.65 48.58 N 49.88 E 6003890.42 N 388278.28 E 3.729 46.35 954.11 20.290 42.350 892.79 943,89 69.45 N 69.41 E 6003911,00 N 388298.12 E 5.076 66.35 1046.73 24.870 43.430 978.29 1029,39 95.47 N 93.63 E 6003936,66 N 388322.73 E 4.965 91.30 1141.95 28.020 43,790 1063.53 1114,63 126.17 N 122.88 E 6003966,91 N 388352.43 E 3.312 120.69 1237.70 29.400 41.800 1147.51 1198.61 159.93 N 154,11 E 6004000,20 N 388384.16 E 1.753 153.05 1333.21 31.380 39.350 1229.90 1281.00 196.64 N 185.50 E 6004036.44 N 388416.11 E 2.445 188.36 1428.60 38.130 40.250 1308.22 1359,32 238.37 N 220.32 E 6004077,64 N 388451.54 E 7.096 228,53 1522.75 42.050 41.310 1380.24 1431,34 284.25 N 259.93 E 6004122.93 N 388491.84 E 4.226 272.64 1618.36 42,330 41.050 1451.08 1502,18 332.58 N 302.21 E 6004170.62 N 388534.83 E 0.345 319,08 1713.09 42.570 41.790 1520.98 1572.08 380.53 N 344.51 E 6004217.92 N 388577.85 E 0.585 365.14 1808.60 45.430 42.020 1589.67 1640.77 429.90 N 388.82 E 6004266.63 N 388622.89 E 2.999 412,53 1904,06 48.550 42.980 1654.78 1705.88 481.34 N 435,98 E 6004317.36 N 388670.82 E 3.350 461.87 1998.71 52,100 42.160 1715.20 1766.30 534.99 N 485.24 E 6004370.27 N 388720.88 E 3.809 513,32 . 2093,60 53,900 41.700 1772.31 1823.41 591.37 N 535.88 E 6004425.88 N 388772,35 E 1.936 567.44 2188.79 51,830 41.920 1829.77 1880.87 647.93 N 586.47 E 6004481.68 N 388823.78 E 2.182 621.74 2284,21 52.490 42.040 1888.30 1939.40 703.95 N 636.87 E 6004536.94 N 388875.02 E 0.699 675.50 2379.11 51.060 41.490 1947,02 1998.12 759,55 N 686.53 E 6004591.79 N 388925.50 E 1.574 728.89 2474,57 50,740 41,500 2007.23 2058.33 815.04 N 735.61 E 6004646.54 N 388975.41 E 0.335 782,18 2569.57 50.400 41,410 2067.56 2118.66 870.04 N 784.19 E 6004700,80 N 389024.81 E 0,365 835.00 2664.95 51.340 41,240 2127.76 2178.86 925.60 N 833.04 E 6004755.62 N 389074.49 E 0.995 888.38 2760,24 52.060 43.440 2186.82 2237.92 980.86 N 883.41 E 6004810.13 N 389125.68 E 1.963 941.40 2855.25 52.140 43.460 2245. 18 2296.28 1035,29 N 934.97 E 6004863.78 N 389178.05 E 0.086 993,52 2950.42 52.200 44.190 2303.55 2354.65 1089.52 N 987.02 E 6004917,22 N 389230.90 E 0.609 1045.43 3014.65 51.930 44,570 2343.04 2394.14 1125.73 N 1022.45 E 6004952,89 N 389266,87 E 0,628 1080.06 3098.94 52.360 44.190 2394.76 2445.86 1173.30 N 1069.00 E 6004999.76 N 389314.13 E 0.622 1125.55 29 April, 2005 - 10:53 Page 2 of8 DrillQuest 3.03.06.008 ConocoPhillips Alaska, Inc. Survey Report for CD3-108 Your Ref: 501032050700 Job No. AK-ZZ-3591167, Surveyed: 9 April, 2005 Alaska North Slope North Slope, Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 000) 3194.28 52.530 44.570 2452.88 2503.98 1227.31 N 1121.86E 6005052.98 N 389367.79 E 0.363 1177.21 3289.53 52.190 43.980 2511.05 2562.15 1281.32 N 1174,52 E 6005106.19 N 389421.25 E 0.607 1228.87 3385,83 52.630 43.810 2569.79 2620.89 1336,31 N 1227.42 E 6005160.38 N 389474.97 E 0.478 1281.49 3481.30 53.300 42.260 2627,29 2678.39 1392.01 N 1279.43 E 6005215.30 N 389527.81 E 1.474 1334.88 3576.47 53.040 42.500 2684,34 2735.44 1448.28 N 1330,77 E 6005270.79 N 389579.99 E 0.340 1388.86 3671.49 52.700 42,250 2741.70 2792.80 1504.25 N 1381.83 E 6005325.99 N 389631.88 E 0.415 1442,54 . 3766.32 52.600 42,810 2799.23 2850.33 1559.80 N 1432.79 E 6005380.77 N 389683.66 E 0.481 1495,82 3862.39 52.230 43.020 2857.83 2908.93 1615.55 N 1484.63 E 6005435.74 N 389736.33 E 0.422 1549,26 3957.79 52,190 42.490 2916.29 2967.39 1670.91 N 1535.81 E 6005490.33 N 389788,33 E 0.441 1602.33 4053.18 52.070 43.350 2974.84 3025.94 1726.05 N 1587.08 E 6005544.70 N 389840.43 E 0.723 1655,18 4148.61 52.130 42.450 3033.47 3084.57 1781.21 N 1638.34 E 6005599.08 N 389892.51 E 0.747 1708.06 4243,98 51,890 41.820 3092.17 3143.27 1836,95 N 1688.77 E 6005654,06 N 389943.76 E 0,578 1761.54 4339,61 51.550 41.840 3151.41 3202.51 1892,89 N 1738.83 E 6005709.24 N 389994.66 E 0,356 1815.24 4435.23 51.590 42.490 3210.85 3261.95 1948.41 N 1789.11 E 6005764.00 N 390045.77 E 0,534 1868,51 4530.61 51.370 43,010 3270.25 3321.35 2003,21 N 1839.77 E 6005818.04 N 390097.24 E 0.485 1921.05 4623.32 52.270 42.840 3327,55 3378,65 2056.57 N 1889.40 E 6005870.65 N 390147.66 E 0.981 1972.20 4721.65 52.030 42.210 3387.89 3438,99 2113.79N 1941,88 E 6005927.08 N 390200.99 E 0.562 2027,08 4817.08 50.710 41,580 3447.46 3498.56 2169.28 N 1991.66 E 6005981.82 N 390251.60 E 1.476 2080.34 4912.40 50.400 41.490 3508.02 3559,12 2224.38 N 2040.47 E 6006036.18 N 390301.23 E 0.333 2133.26 5007.66 50.140 42.360 3568.91 3620.01 2278,89 N 2089.42 E 6006089.95 N 390350.99 E 0.754 2185,58 5103.25 49.860 41.200 3630.36 3681.46 2333.49 N 2138.21 E 6006143.81 N 390400.59 E 0,975 2238.00 5198.58 49.670 42.180 3691,93 3743,03 2387.83 N 2186,61 E 6006197.43 N 390449.80 E 0.810 2290.18 5294.15 49.110 41.870 3754,14 3805.24 2441,73 N 2235,18 E 6006250.59 N 390499.17 E 0,636 2341,91 . 5389.59 49.990 41.730 3816,06 3867.16 2495,87 N 2283,59 E 6006304.00 N 390548.38 E 0,929 2393.89 5485.23 49.840 41.960 3877.65 3928,75 2550.38 N 2332.40 E 6006357.77 N 390598.01 E 0.242 2446.22 5580.32 50.000 41.440 3938,87 3989.97 2604.70 N 2380.80 E 6006411.37 N 390647.21 E 0.451 2498.38 5676,10 49.780 41.430 4000.58 4051,68 2659.62 N 2429.28 E 6006465.55 N 390696.51 E 0.230 2551.13 5771,53 50.370 42.510 4061,82 4112.92 2714,03 N 2478.22 E 6006519.22 N 390746.26 E 1,066 2603.35 5866,92 49,900 42.160 4122.97 4174,07 2768.15 N 2527.53 E 6006572.60 N 390796.37 E 0.568 2655.27 5962.53 49,960 42.370 4184.51 4235,61 2822.30 N 2576.74 E 6006626.00 N 390846.39 E 0.179 2707.22 6057.72 50.000 41.850 4245.73 4296,83 2876.38 N 2625,62 E 6006679.35 N 390896.07 E 0.420 2759,11 6153.40 49.980 41.880 4307.24 4358,34 2930.96 N 2674,53 E 6006733.18 N 390945.79 E 0,032 2811,51 6248.64 49.930 42.050 4368,52 4419.62 2985.17 N 2723.28 E 6006786.66 N 390995,35 E 0,146 2863.54 6344.00 50.280 42,900 4429.68 4480.78 3039,13 N 2772.69 E 6006839.87 N 391045.56 E 0.776 2915.29 6439.36 50.660 42.260 4490,37 4541.47 3093.29 N 2822.45 E 6006893.28 N 391096.13 E 0.653 2967.23 29 April, 2005 - 10:53 Page 3 of8 DrillQuest 3.03.06.008 ConocoPhillips Alaska, Inc. Survey Report for CD3-108 Your Ref: 501032050700 Job No. AK-ZZ-3591167, Surveyed: 9 April, 2005 Alaska North Slope North Slope, Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6534.72 51.550 42.550 4550.25 4601.35 3148.09 N 2872.50 E 6006947.33 N 391147.00 E 0.963 3019.80 6630.09 52.240 43.070 4609.10 4660,20 3203.14 N 2923.50 E 6007001.61 N 391198.81 E 0.841 3072,57 6725.53 52,760 42.680 4667,20 4718.30 3258,63 N 2975.02 E 6007056.32 N 391251.16 E 0.634 3125.76 6820.86 53.080 42,820 4724.68 4775.78 3314.48 N 3026.64 E 6007111,39 N 391303,61 E 0.356 3179.30 6916,29 52.350 42,610 4782.49 4833.59 3370,26 N 3078.15 E 6007166.40 N 391355.95 E 0.785 3232.79 7011.78 52.630 42.710 4840.63 4891.73 3425.97 N 3129.48 E 6007221.33 N 391408.10 E 0.305 3286,20 . 7107.36 51.550 42.370 4899,36 4950.46 3481.53 N 3180.46 E 6007276.12 N 391459.92 E 1.164 3339.48 7202,87 51.830 42.320 4958.57 5009.67 3536.92 N 3230,95 E 6007330.75 N 391511.22 E 0.296 3392.62 7298.34 52.190 41.110 5017.33 5068.43 3593.08 N 3281.01 E 6007386.15 N 391562,12 E 1.068 3446.55 7393,89 52.190 38.530 5075.92 5127,02 3651,05 N 3329.34 E 6007443.40 N 391611.32 E 2.133 3502.36 7489.49 52.120 38.890 5134.57 5185.67 3709.96 N 3376.56 E 6007501.59 N 391659.41 E 0.306 3559.15 7584,76 51.410 37.440 5193.53 5244,63 3768,79 N 3422.80 E 6007559.72 N 391706.52 E 1.409 3615.91 7680.27 51.540 37.180 5253.02 5304.12 3828.22 N 3468,09 E 6007618.47 N 391752.70 E 0.253 3673.30 7775.58 51.940 37,280 5312.04 5363.14 3887,81 N 3513.37 E 6007677.37 N 391798.86 E 0.428 3730.86 7870.79 51.860 37.010 5370.79 5421,89 3947,53 N 3558.61 E 6007736.41 N 391845,00 E 0.238 3788,55 7966.31 51.490 36,590 5430.02 5481.12 4007.54 N 3603.50 E 6007795.73 N 391890.78 E 0.519 3846.54 8061.63 51.520 36.310 5489.35 5540.45 4067.54 N 3647,82 E 6007855.07 N 391935.99 E 0.232 3904.56 8156.97 51.580 37.810 5548.64 5599.74 4127.13N 3692.82 E 6007913.97 N 391981,88 E 1.234 3962.12 8252.62 51.760 43.240 5607.99 5659,09 4184,12N 3741.54 E 6007970.23 N 392031,45 E 4.457 4016,93 8347,78 51.210 42.650 5667.25 5718,35 4238,62 N 3792.27 E 6008023.96 N 392082.99 E 0.755 4069.17 8443.20 51.170 41.210 5727,05 5778.15 4293.93 N 3841.95 E 6008078.53 N 392133.49 E 1.177 4122.26 8537.96 51.400 40.470 5786.32 5837.42 4349,87 N 3890,30 E 6008133.73 N 392182.68 E 0,656 4176.04 8634,10 51.510 40.370 5846.23 5897,33 4407.12 N 3939.06 E 6008190.24 N 392232,28 E 0.140 4231.10 . 8729.32 52.170 40.400 5905,06 5956.16 4464.15 N 3987.57 E 6008246,54 N 392281.64 E 0.694 4285.96 8823.06 52.090 38.130 5962.61 6013.71 4521.43 N 4034.40 E 6008303.12 N 392329.32 E 1.913 4341,15 8920.34 51.950 37.430 6022.48 6073.58 4582.03 N 4081.37 E 6008363.01 N 392377,20 E 0.585 4399.65 9015.81 51,740 37.900 6081.46 6132.56 4641.46 N 4127.24 E 6008421.74 N 392423.96 E 0.445 4457.01 9111.23 51.800 37.250 6140.50 6191.60 4700.87 N 4172,95 E 6008480.46 N 392470.55 E 0.539 4514,37 9206.71 53.000 32.500 6198,78 6249.88 4762.91 N 4216.16 E 6008541,85 N 392514.68 E 4.136 4574.47 9302.08 54.470 30,910 6255.19 6306,29 4828.33 N 4256.56 E 6008606.66 N 392556.06 E 2.045 4638.07 9397.88 54,890 28,300 6310.59 6361.69 4896.28 N 4295.17 E 6008674,03 N 392595.68 E 2.266 4704.27 9493,28 55.380 26.750 6365.12 6416.22 4965.70 N 4331.34 E 6008742.89 N 392632,88 E 1.429 4772.04 9588,68 55.990 23.030 6418.92 6470.02 5037.16 N 4364.48 E 6008813.85 N 392667.09 E 3.283 4841.99 9684.12 60.860 14.610 6468.94 6520.04 5114.04 N 4390.52 E 6008890.33 N 392694.28 E 9.079 4917,66 9779.80 59,530 11.250 6516.51 6567,61 5194.94 N 4409.11 E 6008970,94 N 392714.08 E 3.349 4997.67 29 April, 2005 - 10:53 Page4of8 DrillQuest 3.03.06.008 ConocoPhillips Alaska, Inc. SUlVey Report for CD3-10B Your Ref: 501032050700 Job No. AK-ZZ-3591167, SUlVeyed: 9 April, 2005 Alaska North Slope North Slope, Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9875.16 59.900 8,110 6564.61 6615.71 5276.10 N 4422.95 E 6009051.88 N 392729.13 E 2.870 5078.15 9970.63 60.820 3,370 6611.84 6662.94 5358.62 N 4431.23 E 6009134.28 N 392738.65 E 4.421 5160.24 10066,10 62.140 358,870 6657.44 6708.54 5442.46 N 4432.85 E 6009218.08 N 392741.52 E 4.366 5243.92 10161,59 63.480 355,810 6701,08 6752.18 5527.29 N 4428.89 E 6009302.96 N 392738.84 E 3.177 5328.84 10256,99 65.480 352.020 6742.19 6793.29 5612.87 N 4419.75 E 6009388.66 N 392730.97 E 4.153 5414.74 10352.46 69.570 348.730 6778.69 6829.79 5699,80 N 4404.97 E 6009475.81 N 392717.49 E 5.337 5502.24 . 10447.62 71.780 344.910 6810.19 6861.29 5787,21 N 4384.48 E 6009563.51 N 392698.32 E 4.443 5590.45 10543.26 74,050 342.760 6838.29 6889.39 5875.00 N 4359.02 E 6009651,67 N 392674.17 E 3,202 5679.27 10638.67 75.060 338,630 6863,71 6914.81 5961.77 N 4328.62 E 6009738.89 N 392645.07 E 4.304 5767.28 10732.77 76.270 333.440 6887.02 6938.12 6045.04 N 4291.59 E 6009822,70 N 392609.30 E 5.496 5852.09 10826.72 n080 330.020 6908,68 6959,78 6125.54 N 4248.29 E 6009903.84 N 392567.21 E 3.646 5934.40 10924,92 80.380 327.740 6927.87 6978,97 6207,96 N 4198.52 E 6009987,00 N 392518.68 E 4.059 6018.92 11020.44 83.050 325.070 6941,64 6992.74 6286.68 N 4146.22 E 6010066.49 N 392467.57 E 3.932 6099.84 11056.70 84,620 323.620 6945.53 6996,63 6315.97 N 4125.21 E 6010096.10 N 392446.99 E 5.878 6130.02 11088.55 86.600 325.380 6947.97 6999.07 6341.82 N 4106.77 E 6010122.22 N 392428,94 E 8.307 6156.65 11120,27 88.700 326.190 6949.27 7000,37 6368.03 N 4088.95 E 6010148,69 N 392411.52 E 7.095 6183.61 11153.31 89.300 326.880 6949.85 7000.95 6395.59 N 4070.73 E 6010176.52 N 392393.72 E 2.767 6211.94 11215.99 89.130 327.930 6950.71 7001.81 6448.39 N 4036,97 E 6010229.82 N 392360.75 E 1.697 6266.16 11311.59 87,160 326.960 6953.80 7004.90 6528.92 N 3985.56 E 6010311.11 N 392310.55 E 2.297 6348.86 11407.07 87.900 327.710 6957.91 7009.01 6609,22 N 3934,07 E 6010392.18 N 392260.27 E 1.103 6431.33 11502.63 91.050 327.620 6958.79 7009.89 6689.95 N 3882.97 E 6010473,66 N 392210.38 E 3.298 6514.21 11597,97 89.560 330.350 6958.28 7009.38 6771,65 N 3833.85 E 6010556.09 N 392162.49 E 3.262 6597.98 11693,61 91.730 330.710 6957,21 7008.31 6854.91 N 3786.81 E 6010640.04 N 392116.70 E 2.300 6683.20 . 11789,31 91.910 328.680 6954.17 7005.27 6937.48 N 3738,54 E 6010723.33 N 392069.68 E 2.128 6767.81 11884.75 92.710 325.450 6950,32 7001.42 7017.51 N 3686.70 E 6010804.12 N 392019.04 E 3.484 6850.02 11980.12 93.570 323.880 6945.09 6996.19 7095.19 N 3631.63 E 6010882.62 N 391965,14 E 1.875 6930,03 12071.43 92.160 321.920 6940.53 6991.63 7167.92 N 3576.62 E 6010956,16 N 391911.23 E 2.642 7005,09 12170,91 90.740 321.980 6938.01 6989.11 7246.23 N 3515,33 E 6011035.38 N 391851.11 E 1.429 7086.00 12266.56 89.500 319.940 6937.81 6988,91 7320.52 N 3455.09 E 6011110,56 N 391791,99 E 2.496 7162.84 12361.95 88.450 317.550 6939.52 6990.62 7392,21 N 3392.20 E 6011183,19 N 391730.19 E 2.736 7237,21 12457.34 89,070 317.550 6941.58 6992.68 7462.58 N 3327.84 E 6011254.52 N 391666.88 E 0.650 7310.32 12552.76 89,690 318.420 6942.62 6993.72 7533.47 N 3263.97 E 6011326,35 N 391604.09 E 1.120 7383,93 12648,12 88.580 320.390 6944.06 6995.16 7605.87 N 3201,93 E 6011399.67 N 391543.14 E 2.371 7458.96 12742.71 89.190 320.190 6945.90 6997.00 7678.62 N 3141,51 E 6011473.32 N 391483.81 E 0.679 7534.28 12839.12 89,870 322.710 6946.69 6997.79 7754.01 N 3081.44 E 6011549.60 N 391424,87 E 2.707 7612,22 29 April, 2005 - 10:53 Page 50fB DrillQuest 3.03. 06. OOB ConocoPhillips Alaska, Inc. Survey Report for CD3-108 Your Ref: 501032050700 Job No. AK-ZZ-3591167, Surveyed: 9 April, 2005 Alaska North Slope North Slope, Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1000) 12934.44 88.890 323.640 6947.72 6998.82 7830,30 N 3024,31 E 6011626.74 N 391368.89 E 1.417 7690.93 13030.00 90.800 326,240 6947,98 6999.08 7908.51 N 2969.42 E 6011705,77 N 391315.18 E 3,376 7771.46 13125.43 91.540 326.430 6946.03 6997.13 7987.92 N 2916.53 E 6011785.96 N 391263.49 E 0.801 7853.10 13220,78 92,280 325.940 6942.85 6993.95 8067,10 N 2863.50 E 6011865.92 N 391211.65 E 0.931 7934.52 13316,32 91.540 326.530 6939.67 6990.77 8146.48 N 2810.43 E 6011946,08 N 391159,77 E 0,990 8016.13 13411.92 90.490 327.260 6937,97 6989.07 8226.54 N 2758,23 E 6012026.92 N 391108.77 E 1.338 8098.40 . 13507,39 90.000 328.940 6937.56 6988.66 8307.59 N 2707,78 E 6012108,72 N 391059,54 E 1,833 8181.57 13602.25 89.750 332.670 6937,77 6988,87 8390.39 N 2661.52 E 6012192,20 N 391014.53 E 3.941 8266.31 13697.75 91.170 334.180 6937.01 6988.11 8475.79 N 2618,80 E 6012278.23 N 390973.09 E 2.170 8353.49 13793.28 92.160 334.510 6934.23 6985.33 8561,86 N 2577.45 E 6012364.91 N 390933.04 E 1.092 8441.29 13888.72 90.920 335.890 6931.66 6982,76 8648.47 N 2537.44 E 6012452.11 N 390894,33 E 1.943 8529.55 13984.03 92.590 341.640 6928.74 6979.84 8737.22 N 2502.95 E 6012541.37 N 390861.17 E 6.279 8619.73 14079.36 91.850 339.580 6925,05 6976.15 8827.07 N 2471.32 E 6012631.68 N 390830.89 E 2.295 8710.87 14174.42 92.900 338.690 6921,11 6972.21 8915.82 N 2437.50 E 6012720.93 N 390798.40 E 1.447 8801.01 14269.90 92.100 336.020 6916,95 6968.05 9003.85 N 2400.77 E 6012809.49 N 390763.00 E 2.917 8890.56 14365.79 91.170 335.470 6914,21 6965.31 9091.24 N 2361.40 E 6012897.46 N 390724.93 E 1.127 8979.58 14461.39 90.860 333.050 6912.52 6963,62 9177.33 N 2319.89 E 6012984.17 N 390684.72 E 2,552 9067.40 14556.64 90.490 333,530 6911.39 6962.49 9262.41 N 2277.08 E 6013069.88 N 390643.19 E 0.636 9154,27 14652.01 90.980 335.010 6910.17 6961,27 9348.31 N 2235.68 E 6013156.39 N 390603.08 E 1.635 9241.90 14747.41 91.790 337.120 6907,86 6958,96 9435.48 N 2196.99 E 6013244.13 N 390565.70 E 2.368 9330.67 14842.83 91.480 336.150 6905.14 6956.24 9523.04 N 2159.16 E 6013332.24 N 390529.19 E 1.067 9419.79 14937.79 90,680 336.100 6903.35 6954.45 9609.86 N 2120.74 E 6013419.63 N 390492.07 E 0.844 9508.20 . 15033.38 90.610 337.830 6902.28 6953.38 9697.81 N 2083.34 E 6013508.13 N 390455,99 E 1.811 9597.71 15128.57 92.090 341.100 6900.03 6951.13 9786.92 N 2049,96 E 6013597.73 N 390423.95 E 3.770 9688.18 15223,81 92.960 339.320 6895.84 6946.94 9876.44 N 2017.75 E 6013687.72 N 390393,08 E 2.079 9779.03 15319.21 91.480 336.500 6892.14 6943.24 9964.76 N 1981.90 E 6013776.57 N 390358.56 E 3.336 9868.83 15414.67 92.100 334.780 6889,16 6940.26 10051,67 N 1942.55 E 6013864.06 N 390320.51 E 1.914 9957,38 15510.37 90.240 330.210 6887.20 6938.30 10136.51 N 1898.37 E 6013949,55 N 390277,61 E 5.155 10044.06 15605.52 91.230 324.410 6885.98 6937,08 10216.55 N 1847.01 E 6014030,35 N 390227.45 E 6.183 10126.26 15701.00 89,260 322.140 6885.57 6936.67 10293.07 N 1789.92 E 6014107.72 N 390171.52 E 3.148 10205,20 15796,52 90.980 322.960 6885.37 6936.47 10368.90 N 1731,84 E 6014184.40 N 390114.58 E 1.995 10283.49 15891.96 90.800 322.360 6883.89 6934.99 10444.77 N 1673.96 E 6014261,13 N 390057,84 E 0.656 10361.81 15987,85 89.630 323.010 6883.53 6934.63 10521.03 N 1615,84 E 6014338,26 N 390000.86 E 1.396 10440.53 16083.22 89.940 323.030 6883.89 6934.99 10597.21 N 1558.47 E 6014415.29 N 389944.64 E 0.326 10519.15 16178.80 89.380 319,280 6884.46 6935.56 10671.64 N 1498.53 E 6014490.61 N 389885.83 E 3,967 10596.12 29 April, 2005 - 10:53 Page 60f8 DrillQuest 3.03.06.008 ConocoPhillips Alaska, Inc. Survey Report for CD3-108 Your Ref: 501032050700 Job No. AK-ZZ-3591167, Surveyed: 9 April, 2005 Alaska North Slope North Slope, Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 16274.13 90.060 319.480 6884.92 6936.02 10744.00 N 1436.47 E 6014563.89 N 389824.86 E 0.744 10671.12 16369.35 90.860 320.480 6884.16 6935,26 10816.92 N 1375.24 E 6014637.71 N 389764.73 E 1.345 10746.63 16464.63 89.260 321.910 6884.06 6935.16 10891.16 N 1315.53 E 6014712.84 N 389706.14 E 2.252 10823.41 16560.95 88.450 322.740 6885.98 6937,08 10967.38 N 1256.68 E 6014789.94 N 389648.43 E 1.204 10902.13 16656.42 87.900 323.980 6889.02 6940.12 11043.95 N 1199.73 E 6014867.35 N 389592.64 E 1.420 10981.10 16751.82 88,520 324.560 6892.00 6943.10 11121.35 N 1144.05 E 6014945.58 N 389538.12 E 0.890 11060.86 . 16847.16 88,890 323.680 6894.16 6945.26 11198.58 N 1088.19 E 6015023.63 N 389483.42 E 1.001 11140.46 16942.54 87.770 323.920 6896.94 6948.04 11275.51 N 1031.88 E 6015101.40 N 389428.27 E 1.201 11219.77 17037.83 88.090 324.730 6900,38 6951.48 11352.87 N 976.35 E 6015179.58 N 389373.90 E 0.913 11299.48 17133.22 87.590 324.820 6903.97 6955.07 11430.74 N 921,36 E 6015258.26 N 389320.09 E 0.533 11379.67 17228.52 88.330 326.770 6907,37 6958.47 11509.50 N 867.83 E 6015337.82 N 389267.74 E 2.187 11460.69 17323.92 87.650 329.460 6910.71 6961.81 11590.45 N 817.47 E 6015419.51 N 389218.60 E 2.907 11543.76 17419.71 89.940 330.070 6912.73 6963.83 11673.18 N 769.25 E 6015502.96 N 389171.63 E 2.474 11628.52 17515.27 94.260 331.710 6909.23 6960.33 11756.59 N 722.81 E 6015587.05 N 389126.43 E 4.835 11713.87 17610.59 92,770 330.100 6903.38 6954.48 11839.72 N 676.54 E 6015670.87 N 389081.42 E 2.299 11798.94 17705.32 94.690 328.900 6897.22 6948.32 11921.17 N 628.57 E 6015753.02 N 389034,67 E 2.389 11882.40 17801.58 95.490 326.730 6888.68 6939.78 12002.31 N 577.50 E 6015834.92 N 388984.83 E 2.394 11965.69 17896,05 92.150 327.350 6882.39 6933.49 12081,39 N 526.23 E 6015914.75 N 388934,74 E 3.596 12046.93 17992,50 93.340 326,320 6877.77 6928.87 12162.03 N 473.53 E 6015996.18 N 388883,26 E 1.631 12129.80 18088,09 93.700 325.370 6871.90 6923.00 12240.98 N 419.96 E 6016075.92 N 388830.88 E 1.061 12211.01 18183.61 92.840 324.020 6866.45 6917.55 12318.81 N 364.85 E 6016154.56 N 388776,94 E 1,674 12291.17 18279,26 92,650 323,620 6861,87 6912,97 12395,92 N 308.45 E 6016232.51 N 388721.70 E 0.463 12370.67 . 18374.77 91,720 324,740 6858.23 6909,33 12473,31 N 252,60 E 6016310,73 N 388667.01 E 1.524 12450.42 18470.15 93.760 325.270 6853.67 6904.77 12551.35 N 197.96 E 6016389.58 N 388613.55 E 2.210 12530.77 18565.18 98.350 325.490 6843,65 6894,75 12629.10 N 144.29 E 6016468.12 N 388561.04 E 4.836 12610.78 18658.92 102.480 324.970 6826.70 6877.80 12704.82 N 91.72 E 6016544.62 N 388509,62 E 4.439 12688.72 18755.46 104.850 322.560 6803.89 6854.99 12780.47 N 36,29 E 6016621.10 N 388455.33 E 3.451 12766.73 18850,94 103.770 323.050 6780.30 6831.40 12854.17 N 19.64 W 6016695.62 N 388400.51 E 1.236 12842.79 , 18915.00 103.770 323.050 6765.05 6816.15 - 12903.89 N 57.04 W '" 6016745.90 N 388363,86 E 0.000 12894.10 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB=51.10" above MSL. Northings and Eastings are relative to 3931" FNL & 816" FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from 3931" FNL & 816" FEL and calculated along an Azimuth of 357.500° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 18915.00ft., 29 April, 2005 - 10:53 Page 7 of 8 DrillQuest 3.03.06.008 ConocoPhillips Alaska, Inc. Survey Report for CD3-108 Your Ref: 501032050700 Job No. AK-ZZ-3591167, Surveyed: 9 April, 2005 Alaska North Slope North Slope, Alaska The Bottom Hole Displacement is 12904.02ft" in the Direction of 359.747° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 18915.00 6816.15 12903.89 N 57,04 W Projected Survey . Survey too/IJroaram for CD3-108 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 0.00 18915.00 6816.15 MWD+IIFR+MS+SAG . 29 April, 2005 -10:53 Page 8 of8 DrillQuest 3.03.06.008 FORM 10-405 Fiord WELL NUMBER API NUMBER 50- CD3-108 103-20507-00 Conoc;:JP'hiUips Ala$ka,lnc. ALASKA OIL AND GAS CONSERVATION COMMISION MONTHLY PRODUCTION REPORT ALPINE PARTICIPATING AREA FIELD - ALPINE PARTICIPATING AREA OPERATOR - CONOCOPHILLlPS ALASKA, INC PRODUCTION MONTH· 04-2005 TYPE FIELD MTH DAYS AVG DAILY DAILY DAILY TOTAL TOTAL TOTAL CODE PROD TUBING AVERAGE AVERAGE AVERAGE OIL WATER GAS PRESSURE OIL WATER GAS (BBL) (BBL) (MCF) 1 N/A 5 550 3,140 0 0 15,700 0 0 Total 15,700 0 0 . . Page 1 of 1 c:ø§ -033 ConocJÃ,illips RE . . }UN 1 .4., ìr¡rJh: L,L\ .} Transmittal #465 Detail Date: 6/9/2005 To (External Party): Email: steve_davies@admin.state.ak.us First Name: Steve Last Name: Davies Phone (907)793-1235 Number: Company: State of AK-AOGCC Address: 333 W.7th Ave,Suite 100 City: Anchorage State: AK Zip Code: 99501 i\¡a~k' ')'" '.1 .) a (II & From (PAl Contact):4y;r:hot2[.'ü Email: Jeanne.L.Haas@conocophillips.com First Name: Jeanne Last Name: Haas Phone 907-263-4470 Number: Company: ConocoPhillips AK Address: ATO 810 700 G St. Ci1y: Anchorage State: AK Zip Code: 99501 Sent Via: Hand over in person Justification: Compliance Transmittal Info: Tracking #: Data Detail: Description PowerWell Services Surface Well Test Report for CD3-108 Quantity 1 Attachments: Filename: None ....... Received By: Signature. Approver: Signature: Type CD Filesize: N/ A &; ./-S-OÇ Date: Date: http://www.ak.ppco.com/transmittal/print.asp ?transno=465 6/9/2005 . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . DEFINITIVE Re: Distribution of Survey Data for Well CD3-108 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 18,915.00' MD (if applicable) 30-Apr-05 PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 1LJ (JjU Date ç MjÂ¡r Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Car' Ulrich Survey Manager Attachment(s) ). !J .>---~ ~ <. . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD3-108(mwd) Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 18,915.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 t1 / 11 ' I Date >~ fI1'J ~I~ Signed ~~ 6dv/ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 30-Apr -05 Àb>- - ~<~:> STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION . . Mechanical Integrity Test Email to:JimReQQ~admin.state.ak.us:BobFleckenstein~admin.state.ak.us OPERATOR: ConocoPhillips Alaska Inc FIELD I UNIT / PAD: Alpine CD3 DATE: 4/11/2005 OPERA TOR REP: David Burley AOGCC REP: welllcD3-10B I Inj. Typel N P,T.D. 205-033 Test Type P Notes: Packer Depth TVDI 6,695' Tubing Test psi 3500 IA OA Pretest Initial 15 Min. 30 Min, 45 Min. 60 Min, 1,040 1,525 1,610 1,610 o 3,500 3,420 3,400 Interval PIF I P MIT Report Form Revised: 03/18/04 CD3-108 MIT Form for Operators - Dee 2004.xls Re: l.2uestlOll about CD3-1 08 . e O'S~ ..0C Subject: Re: Question about CD3-108 ~ -,-,);:;> - From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Tue, 05 Apr 2005 10:06:15 -0800 To: "Allsup-Drake, Sharon K" <Sharon.K.Allsup-Drake@conocophillips.com> cc: Steve McMains <steve_mcmains@admin.state.ak.us>, Steve Davies <steve _ davies@admin.state.ak.us> Sharon, In that case no paperwork is needed. Just be sure that the production is reported. Any production needs to be specifically reported. Since this will be new pool, one of two possible at CD-3, new pools codes may be necessary. I have copied this to the Steves over here for coordination. There is work underway with regard to pool rules for Fiord and Nanuq. Tom Maunder Allsup-Drake, Sharon K wrote: Tom - it will take 10 days or less. Thanks, Sharon office phone: 263-4612 fax: 265-6224 -----Original Message----- From: Thomas Maunder rmailto:tom maunder@admin.state.ak.us] Sent: Monday, April 04, 20054:23 PM To: Allsup-Drake, Sharon K Subject: Re: Question about CD3-108 Sharon, Are we talking about a week or so?? 30 days is usually the break point about having it as a producer or injector. Tom Allsup-Drake, Sharon K wrote: Tom - we are currently drilling CD3-108 and we permitted it as an injector. We would like to flow it back and do a short production test. Do we need to submit an application for sundry to AOGCC to do this work? Thanks, Sharon office phone: 263-4612 fax: 265-6224 1 of 1 4/5/2005 10:06 AM · STATE OF ALASKA . OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: Hm reQQ@admín.state,ak,us aogcc prudhoe bav@adm~n.state.ak.us bob f¡eckenste~n@adm¡n.state.ak,us Rig No.: 19 DATE: 4/1/2005 Rig Phone: 670-4302 Rig Fax: 670-4303 Op. Phone: 670-4300 Op. Fax: 670-4301 11/09/04 Contractor: Doyon Rig Rep.: WelshlGrazulis Operator: Conoco Phillips Alaska Rep.: MickeylThorton FieldlUnit & Well No.: Colville Rv CD3-108 Operation: Test: Test Pressure: Drlg: X Initial: Rams: 250/5000 MISC. INSPECTIONS: Test Result Location Gen.: P Housekeeping: P PTD On Location P Standing Order Posted P BOP STACK: Quantity 1 1 1 1 1 2 1 o Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve MUD SYSTEM: Visual Test Trip Tank P Pit Level Indicators P Flow Indicator P Meth Gas Detector P H2S Gas Detector P Well Sign Dr!. Rig Hazard Sec. Size 13-5/8 3-1/2x 6 3-1/2x 6 blinds 3-1/8 3-1/8 3-1/8 Alarm Test P P P P P PTD # 205-033 Workover: Weekly: X Annular: 250/3500 TEST DATA Test Result P P P Test Result P P P P P P P NA Explor.: Bi-Weekly Valves: 250/5000 FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Result No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: TimelPressure Test Result System Pressure 3000 P Pressure After Closure 1550 P 200 psi Attained 30 sec P Full Pressure Attained 2 min 20 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4 @2300 Test Results Number of Failures: º Test Time: 4.5 Hours Components tested 28 Repair or replacement of equipment will be made within nla days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: Hm reQQ~admín.state,ak,us Remarks: Smooth test 24 HOUR NOTICE GIVEN YES X NO Date 03/30105 Waived By Time 4:00:00PM Jeff Jones Witness Test start 2:00PM 4-01- Finish )1/0504:30: PM John Welsh BOP Test (for rigs) BFL 11/09/04 Doyon19 04-01-05 CD3-108.xls · STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: íìm reQg~admin.state.ak,us aogcc prudhoe bay@adm;n.state.ak.us bob fîeckenste¡ntmadmín.state,ak,us Rig No.: 19 DATE: 3/25/2005 Rig Phone: 670-4302 Rig Fax: 670-4303 Op. Phone: 670-4300 Op. Fax: 670-4301 11/09/04 Contractor: Doyon Rig Rep.: KrupalGrazulis Operator: Conoco Phillips Alaska Rep.: Burley/HiII FieldlUnit & Well No.: Colville Rv CD3-108 Operation: Test: Test Pressure: Drlg: X Initial: X Rams: 250/5000 MISC. INSPECTIONS: Test Result Location Gen.: P Housekeeping: P PTD On Location P Standing Order Posted P BOP STACK: Quantity 1 1 1 1 1 2 1 o Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve MUD SYSTEM: Visual Test Trip Tank P Pit Level Indicators P Flow Indicator P Meth Gas Detector P H2S Gas Detector P Well Sign Dr!. Rig Hazard Sec. Size 13-5/8 3-1/2x 6 3-1/2x 6 blinds 3-1/8 3-1/8 3-1/8 Alarm Test P P P P P . PTD # 205-033 Workover: Weekly: Annular: 250/3500 TEST DATA Test Result P P P Test Result P P P P P P P NA Explor. : Bi-Weekly Valves: 250/5000 FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Result No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: TimelPressure Test Result System Pressure 3000 P Pressure After Closure 1550 P 200 psi Attained 31 sec P Full Pressure Attained 2 min 57 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4 @2400 Test Results Number of Failures: º Test Time: 5.00 Hours Components tested 28 Repair or replacement of equipment will be made within n/a days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: íìm reQgtmadmín.state,ak,us Remarks: Good test 24 HOUR NOTICE GIVEN YES X NO Date 03/24/05 Time Waived By 6:00:00PM John Crisp Witness Test start ,:00PM 3-25-( Finish 25/05 10:00: PM Ed Grazulis BOP Test (for rigs) BFL 11/09/04 Doyon19 03-25-05 CD3-108.xls . STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Submit to: torn_l11i3.unde:@adl11in.st<::te.ak,us aúgcc..}m¡d h08...bay@admin.state,ak,us b(;b...f¡E:Gk~mstE;in@¡3drn!n .statø. ak. ¡;~; Date: 22-Mar-05 x Exploratory: 205-033 Rig Ph. # 670-4300 Drlg Contractor: Doyon Operator: Conoco Phillips Alaska Inc, Field/Unit & Well No.: CD3-108 Location: Sec. 5 T. T12N ....................... . . . . . . . . . . . . . . . . . " . . ........ . . . . . . . . . . ........ . ................................ . . . . . . . . . . . . . . . . ............... . . . . . . . . . . . . . . . . . .......... -....... .." . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .................... . . . . . . . . . . . . . . ........ . ...................... . ................................................ ............. . MISC. INSPECTIONS: Location Gen.: OK Housekeeping: P Reserve Pit: NIA Well Sign: (Gen.) Drlg, Rig: Flare Pit: DIVERTER SYSTEM INSPECTION: Diverter Size: 20 Divert Valve(s) Full Opening: YES Valve(s) Auto & Simultaneous: YES Vent Line(s) Size: 16 Vent Line(s) Length: 85 Line(s) Bifurcated: NIA Line(s) Down Wind: YES Line(s) Anchored: YES Turns Targeted I Long Radius: NIA in, in, ft. R. Operation: Rig No, Oper, Rep,: Rig Rep,: R5E Development 19 PTD # Hill I Thorton Krupa I Lupton Merdian UM ',·,"""'T' 'E' ····r· . "0' '~' "T' ',','..,' . . . . . . ." . . /:::«,$ ::: :, >:,A ......... . ........ . ................ . . . . . . . . . . . . . . . . . . .............. . .... ................. ......... . ...... .... ........ . ....... .. ., . ......... ..... ............. . ............. . ............................ ............ . .. ..................:-:.;.:<:::::::::::.:::::.::;::::: P P NIA ACCUMULATOR SYSTEM: Systems Pressure: 2900 psig Pressure After Closure: 1550 psig 200 psi Attained After Closure:_ min ~ sec, Systems Pressure Attained: 2 mim 54 sec. Nitrogen Bottles: 4 @ 2300 psi average psig MUD SYSTEM INSPECTION: Trip Tank: Mud Pits: Flow Monitor: Light P P P Alarm P P P GAS DETECTORS: Methane Hydrogen Sulfide: Light P P Alarm p P ................ . ................. . · . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . · . . . . . . . . . . . . . . . . ................. . ................ . . . . . . . . . . . . . . . . . . . ................ . ................. . · . . . . . . . . . . . . . . . . ................. . ........ . ...................... . ..................... . . . . . . . . . . . . . . . . . . . . . ...... .............. . . . . . . . . . . . . . . . . . ............... . ............ . ::.::::::::::::..::.:..::.....:::.:..:..........:.:..........:..:...:.. ::·...····.,.;:,:þWi$RTt:R$çHSMAl'1p..:. IRIG 19 SUB Non Compliance Items ~ Repair Items Withir Remarks: Test went good Diverter Test (for rigs) BFL 11120100 ............ ........... ... ........................ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . II Div, Vent line I þ NIA Day (s) And contact the Inspector @ 659-3607 AOGCC REP.: Witnessing waived by Chuck Scheve OPERATOR REP,: HilllThorton DiverterTest CD3-108 Doyon 19, 3-22-05,xls . . ~. T¡ !%ß lIUI fE I[illO·. rb . ;! , . Ie U! ~U '.. ~ 1 . ~T I" ~ 'fù nr¡ 17\8 IIJ ¡ [KJ b \. l.\ ¡ Y.: (... I.. . '\' I! ,~\\·"I.I ¡,L- 1 rul I !\\ u,!,"",\ \ u r-.J U"'~ -iU ! U FRANK H. MURKOWSKI. GOVERNOR AI,ASHA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Colville River CD3-1 08 ConocoPhillips Alaska, Inc. Permit No: 205-033 Surface Location: 3931' FNL, 816' FEL, SEC. 5, TI2N, R5E, UM Bottomhole Location: 904' FNL, 4007' FEL, SEC. 29, T13N, R5E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service well. Prior to placing this well in operation, Area Injection Order 18B and Conservation Order 443A must be amended to include the pool(s) to be developed at CD-3. This permit to drill does not exempt you from obtaining additional permits or approvals required by law fTom other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission 0 witness any required test. Contact the Commission's petroleum field inspector at (907) 65 7 (pager). el DATED this l' day of March, 2005 cc: Department ofFish & Game, Habitat Section w/o encl. . ,t ~/J- PERMIT TO DRILL 20 AAC 25.005 Alaska Oil & Gas COni. COtmûssio: ExploratoryU Development Oil U Am.-horaalultiPle Zone 0 ~;ervice [2] Development Gas 0 Single Zone [2] 5. Bond: ~ Blanket U Single Well 11, Well Name and Number: Bond No. 59-52-180 CD3-108 6, I"roposed Depth: 12. Field/Pool(s): M[): 19769' TVD: 6788' Colville River Field . RECEIVED MAR Ó 1 2005 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 1 a, Type of Work: Drill [2] Re-entry 0 Redrill U 11 b, Current Well Class: Stratigraphic Test 0 2, Operator Name: ConocoPhillips Alaska, Inc. 3, Address: P.O, Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 3931' FNL, 816' FEL, Sec, 5, T12N, R5E, UM Top of Productive Horizon: 2878' FNL, 4584' FEL, Sec, 33, T13N, R5E, UM Total Depth: 904' FNL, 4007 FEL, Sec, 29, T13N, R5E, UM 4b, Location of Well (State Base Plane Coordinates): Surface: x- 388228 16. Deviated wells: Kickoff depth: 300 18. Casing Program Size y- 6003843 ft. Maximum Hole Angle: Specifications Grade Coupling H-40 Weld J-55 BTC L-80 BTC-M L-80 EUE-M Hole 42" 12,25" 8,5" 6,125" Casing 16" Weight 62.5# 36# 26# 12.6# 9,625" 7" 4,5" 19 Total Depth MD (It) 7. I"roperty Designation: ADL 372105,372104,364471 ---S:ï:ãild Use Permit: Fiord 13, Approximate Spud Date: 3/15/2005 LAS21122 ---g:-;~'es in Property: 2560 14, Distance to Nearest Property: 836' FEL, Sec. 5 10, K3 Elevation 15, Distance to Nearest Zone- 4 (Height aiJove GL): .36.7 feet Well within Pool: Fiord 5, 938ft 17, A lticipated Pressure (see 20 AAC 25,035) 96° Max, Downhole Pressure: 3161 psig Setting Depth / Max, Surface Pressure: 2462 psig Quantity of Cement c, f, or sacks (including stage data) portland cement 506 sx AS Lite & 230 sx 15.8ppg 249 sx 15.8 ppg G t.'~"·h'~) Length 77' 3130' 11048' 1 0080' Top Bottom MD TVD MD TVD 37' 37' 114' 114' 37' 37' 3167' 2508' 37' 37' 11085' 6987' 32' 32' 10112' 6744' PRESENT WELL CONDITION SUMMARY Total Depth TVD (It): Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (It): Length Size None 20. Attachments: Filing Fee [2] Property Plat 0 BOP Sketch 0 Diverter Sketch 0 21, Verbal Approval: Commission Representative: (To be completed for Redrill and Re-Entry Operations) I Effective Deplh MD (It): Effective Depth TVD (It): Junk (measured) Cement Volume MD TVD IPerfOration Depth TVD (It): None Drilling Program[2] Time v. Depth Plot 0 Seabed Report 0 Drilling Fluid Program [2] Date: Shallow Hazard Analysis 0 20 AAC 25,050 requirements [2] Printed Name Signature C. Alvord 22, I hereby certify that the foregoing is true and correct to the best of my knowledge, Commission Use :)nly I Permit Approval 2.. 0 5 ð;) Date: :J/Wo ç --- ~ Yes;C] No Mud log required 8 Yes 0 No DYes'~ No Directional survey required 1::81 Yes 0 No <)(JM<';;)S.~ C\ \..:, ",,"v \'"\. ~ \' ~'t \-\. \\ ~ (:"~~""<t~\~vC\ \~~ 'I \() ~<X.\Q~~~" O-~(.~\(. M~ -\ \.«. o.,"","~ Ii.(} \,<"'<),,40 '\' ~~~;:?, "" (' \ \. "':z. 4Ï, > COMMISSIONER THE COMMISSION Date: V / r / ():) :JRIGINAL ,A- c. rÞ- Permit to Drill I API Number: Number:.....20S - o:J 3 50- /03... Conditions of approval: Samples required Hydrogen sulfide measures C:mtact V. Johnson @ 265-6081 Title Alpine Drilling Team Leader Phone ¿fÞ 5- ~ I L-" Date :2.[ "t.-E, ((1 ~ PreDared bv V. Johnson Isee cover letter for other requirements Submit in duplicate . . CD3-108 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) .12-1/4" Hole /9-5/8" Casina Interval Event Risk Level Conductor Broach Low Well Collision Low Gas Hydrates Low Running Sands and Gravel Low Abnormal Pressure in Surface Formations >2000' TVD Lost Circulation Low Low 8-1/2" Hole /7" Casina Interval Event Risk Level Abnormal Pressure in low Surface Formations >2000' TVD Lost circulation Low Hole swabbing on trips Moderate Abnormal Reservoir Pressure low Hydrogen Sulfide gas Low Mitigation Strategy Monitor cellar continuously during interval. Gyro single shots, traveling cylinder diagrams Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud temperatures Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Increased mud weight Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries Mitigation Strategy BOPE drills, Keep mud weight above 9.6 ppg. Check for flow during connections and if needed, increase mud weight. Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Well control drills, increased mud weight. No mapped faults occur within 700' of the planned wellbore. H2S drills, detection systems, alarms, standard well control practices, mud scavengers .6-1/8" Hole / Horizontal Production Hole Event Risk Level Lost circulation moderate Hole swabbing on trips Moderate Abnormal Reservoir Pressure Medium Hydrogen Sulfide gas Low Mitigation Strateqy Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. BOPE drills, Keep mud weight above 8.8 ppg. Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud weight. H2S drills, detection systems, alarms, standard well control practices, mud scavengers ORIGiNAL . . Fiord: CD3-108 Procedure 1. Move on Doyon 19, dewater cellar as needed. 2. Nipple up and test diverter. / 3. Drill 12-W' hole to the surface casing point as per the directional plan. (LWD program GRlRES/DENS/POROSITY) 4. Run and cement 9-5/8" surface casing. 5. Install and test BOPE to 5000 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 8-1/2" drilling BHA. 9. Drill 8-%" hole to intermediate casing point in the Nechelik Sands. (LWD Program: GRlRES/DENS/POROSITY/PWD) 10. Run and cement 7" casing as per program. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 11 . BOPE test to 5000 psi. 12. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 13. Drill 6-1/8" horizontal section to well TD (LWD Program: GRlRES/PWD). 16. Circulate the hole clean and pull out of hole. 17. Run 4-%,12.6#, L-80 tubing with DB injection nipple, gas lift mandrel and packer. Land hanger. 18. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 19. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 20. Circulate tubing to diesel and install freeze protection in the annulus. 21. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi /30 mins. 22. Set BPV and secure well. Move rig off. ORIGINAL . . Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. Fiord 5 will be the closest well. Well separation is 938' @ 13642' MD. Accounting for survey uncertainties, the ellipse-to-ellipse separation is 635' @ 13642' MD. DrillinQ Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Nechelik 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 PumpinQ Operations: Incidental fluids developed from drilling operations on well CD3 -10B will be injected into the class 2 disposal well on CD1 pad. The CD3-108 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 Nechelik reservoir and there will be more than 500' of cement fill above the top of the Nechelik as per regulations. Upon completion of CD3-108 form 10-403, Application for Sundry Operations - Annular Disposal, 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) * (2508') + 1 ,500 psi = 3065 psi Pore Pressure = 1 ,135 psi Therefore Differential = 3065 - 1135 = 1930 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: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1 ,717 psi 3,520 psi 2.992 psi 7" 26 L-BO 3 BTC-Mod 5,410 psi 4.599 psi 7,240 psi 6,154 psi ORIGINAL . . CD3-108 DRilliNG FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 W' Section - 6 1/8" point -12 W Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.0-9.3 ppg 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 I 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 production interval will be drilled with aM-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. ORIGINAL Fiord (CD3) Colville River Field CD3-108 Injection Well Completion Plan 16" Conductor to 114' 4-1/2" Camco DB Nipple (3,812') at 1970' TVO = 2300' MO 9-5/8" 36 ppf J-55 BTC Surface Casing @ 3167' MO 12508' TVO cemented to surface Packer FhJid mix: 9,2 ppg KCI Brine with 2000' TVD diesel cap 4-1/2" 12,6 ppf L-80 1ST M tubing run with Jet Lube Run'n'Seal pipe dope Tubing suspended with diesel TOC @+I- 9555' MD 16461' TVO (1455' MO above top Nechelik) Completion MD TVD Tubing Hanger 32' 32' 4-1/2", 12,6#/ft, IBT-Mod Tubing Camco DB nipple 2300' 1970' 4-1/2", 12,6#/ft, IBT-Mod Tubing Camco KSG2- GLM (3.909" 10) 9040' 6665' 4-1/2", 12,6#/ft, IBT-Mod Tubing (2) Baker Premier Packer 10040' 6712' 4-1/2", 12,6#/ft, IBT-Mod Tubing (1) HES "XN" (3,725")-64,2° inc 10100' 6739' 4-112", 12,6#1ft, 1ST-Mod 10' pup joint WEG 10112' Camco KBG-2 GLM (3.909" ORIFT 10) wI dummy Baker Premier Packer +1- 10040' MOl 6712' TVO < 270' TVO from top of Nechelik --- __n_ ----- ----- --------------- _______mm__ ----- -----------wêíi-T[;-;~-J 19769' MD Ii 678S'TVD ! _~__-----_J ------------------------------------------------------------- Top Nechelik at 11010' MO /6982' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 11085' I 6987' TVD @+I- 87,10 I 1 . . CD3-108 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 (c) (3,4) and as required in 20 ACe 25.035 (d) (2» The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well : Csg Setting Fracture Pore Casing Size Depth Gradient pressure ASP Drilling (in) MD/TVD(ft) (lbs. I gal) (psi) (psi) 16 114/114 10.9 52 53 9 5/8 3168/2508 14.5 1135 1640 7" 11085/6987 16.0 3162 2473 NIA 19769/6788 16.0 3072 NIA . NOTE: The Doyon 195000 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 psi/ft 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 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1] D = [(10.9 x 0.052) - 0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1135 - (0.1 x 2508') = 884 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1] D = [(14.5 x 0.052) - 0.1] x 2508 = 1640 psi OR ASP = FPP - (0.1 x D) = 3162 - (0.1 x 6987') = 2463 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3072 - (0.1 x 6788') = 2393 psi ORIGINAL Cementine: Proe:ram: . .' 95/8" Surface Casine: run to 3167' MD /2508' TVD. Cement from 3167' MD to 2667' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2667' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1795' MD). Lead slurry: System: Tail slurry: System: (2667'-1293') X 0.3132 ft3/ft X 1.5 (50% excess) = 645.5 fe below pennafrost 1293' X 0.3132 fe/ft X 4 (300% excess) = 1619.9 fe above pennafrost Total volume = 645.5 + 1619.9 = 2265.4 fe => 506 Sx @ 4.48 fe/sk 506 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 felsk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% Sool accelerator, 50% D124 extender and 9% BWOW1 D044 freeze suppressant 500' X 0.3132 fe/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 fe/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 fe => 230 Sx @ 1.17 fe/sk 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1 % 5001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk ,7" Intermediate Casine: run to 11085' MD /6987' TVD Cement from 11085' MD to +/- 9555' MD (50% more cement above the Nechelik as there is between the packer and the Nechelik) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Tail: System: (11085' - 9555') X 0.1268 fe/ft X 1.4 (40% excess) = 271.6 ft3 annular vol. 80' X 0.2148 fe/n = 17.2 fe shoe joint volume Total volume = 271.6 + 17.2 = 288.8 fe => 249 Sx @ 1.16 fe/sk 249 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.16 fe/sk 1 By Weight Of mix Water, all other additives are BWOCement ORIGtNAL Fiord (CD3) Colville River Field CD3-108 Injection Well Completion Plan 16" Conductor to 114' 4-1/2" Camco OB Nipple (3.812') at 1970' TVD ::: 2300' MD 9-518" 36 ppf J-55 BTC Suriace Casing @ 3167' MD 12508' TVD cemented to suriace 4-1/2" 12.6 ppf L-80 1ST M tubing run with Jet Lube Run'n'Seal pipe dope Camco KBG-2 GLM (3.909" DRIFT 10) wI dummy Packer Fluid mix: 9.2 PP9 KCI Brine with 2000' TVD die!?el cap Tubing suspended with diesel Completion Tubing Hanger 4-1/2", 12,6#/ft, IBT-Mod Tubing Camco DB nipple 4-1/2", 12,6#/ft, IBT-Mod Tubing Camco KBG2- GLM (3.909" 10) 4-1/2", 12.6#/ft, IBT-Mod Tubing (2) Baker Premier Packer 4-1/2", 12,6#/ft, IBT-Mod Tubing (1) HES "XN" (3.725")-64,2° inc 4-1/2", 12,6#/ft, IBT-Mod 10' pup joint WEG Baker Premier Packer +1- 10020' MOl 6703' TVD < 279' TVD from top of Nechelik TOC @ +1- 9525' MD 16444' TVD (1485' MD above top Nechelik) Top Nechelík at 11010' MD 16982' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 11085' 1 6987' TVO @+I- 87.10 I I M.Q TVD 32' 32' 2300' 9040' 6665' 10040' 6712' 10100' 6739' 10112' 6744' , , ¿ , ' ,- Pt /' . . , "1, í ... '" i~1~cr; ~ H~= _: t-~1j~H' _'@¡Q#Æ,¡, -fm~lr·u:. . ! '" , . , j 1 I . . . ,g ,. · I , i ' ~ . II "''''0 Csg Pt ... Drill out 8-112" Hole: 3148.68aft MrD, 2500.000It TVD "'. ~ ~ - ,- '.1 :'" g>' IF. d ~,- "'-. ~ "'-"@ 1lW.4J m. ." ài I ¡ ,~, '" """: I . I'''' . . I ..' I :. . I I ! I , I ¡ I I ¡ I I i I ¡ I I I I I I I I I ¡ 13500 12000 ê ~ 10500 - o o o ~ '+ 9000 'E t o E: ::::: 7500 .c '5 o (J) 6000 4500 1500 -7500 -6000 ·4500 Calculation Method: Error .system: Scan M"ethod: Error Surface: Warning Method: Minimum Curvature ISCWSA Elliptical Conic Rules Based Trav. Cylinder North w '" II:: Z '" ; '" '" .. .. UJ J 11: ~ '" ... ~ ; ::- i5 6 1/8" <?pen Hole ,_ jCD3.108 (Ptg) I . - CD3-108 ,'-jCD3-108 (Pt 7) I . CD3-108 ICD3'~08 (Pt4) ICD3-108 3) , . /: (Pt2) I ".X II , r.n"l.1()A (Pt 1) , I - "". ii.: '" .. .00 . - ~-, ¡ I I , , I I , I 1 _,_, ·1500 1500 -3OQQ 4500 6000 West(-)/East(+) (3000 SECTION DeTAU III I . ! : I , .. I Y -- ... .. ., , . ,...-¡ . ! " ~I 7500 9000 10500 12000 PINE sI:J·....,....,v...sun pAiLLING S¡;U"VH::::-Ìiii~ ,\ riJi.LUmJirtl»i T 4'PINE Error System: Minimum Curvature Calculation Method: ISCWSA Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic Waming Method: Rules Based ¡Iii Co , ,~L ~" u,L m I:::, I SI!I::'T'D,f ŒTALS ,,""''''''" 00 ,i" ;'-;,' I' See IJ lite A2I TVD iNI-s iE/-W I I'.V\ .'. ¡-' , , 1 ;16.10 0.000 0.000 ;16.100 0.000 0.000 , ' 2 300.00 11.600 I!.OOO $00.000 I!.I 00 11.1:100 , 3 2œ2A6 51.674 41.695 1198.274 541; 2C 482.566 ... ~"^ < un 4 9137.67 51.674 41.695 $21!M!1O 4?O1!.1 4195395 - 5~~~~~~ , 6 ..""...... 86.1114 324.893 6967_ 41211368 ,( , ._ ,_ 7 1268.51' 86.1114 324.893 6991!.591 ~ _, :, \' j 1385.92' 911.1116 324.'162 7OO1'!!00 3961.37.2 1M 9 1385.!1'1; 00,681 324.161 7001.599 3961.341 , .v _~_ 90.881 324.161 1i99O.713 3552.1146 11 œ.285 90.673 324.940 6990.600 l' 1ì5: 3547.523 , c." "'I, """"" ....<I@"<""'" : 00.446 32U62 1!99Q.226 7199224 3S22.11õ6 '\ '''I,m.., ..._v 00.446 323.262 69S5.000 71$l,662 31J!O.ì166 '.' I 91.3œ 334.730 6981!.600 7983.609 2973.1111 , i ' i j ,I \ 91.270 33$.529 6980.152 8001.729 2964,761 (>4, ,,-~V ~ , '" Drill out 8-112" Hole: 3148.688fI MD, 2508.000ft TVD 91.270 335.529 6947.441 9345.1164 23!i3.893 .I. 91.683 324.1142 6!I4O.600 95'1'4J!œ ~ 173 '. _ ~,. _. .. _.' __ _'M _ _ 91.11114 324.1142 6!I4O.600 967il515 ~166 , . ., 324.1142 1ì893.7711œt8.161 1307.1164 , J!O 15465.984 32il'940 6683,600 IØ1!113.1146 1303.396 , 2115465.1 91.436 324.'940 6683.5981Ø1!113.924 1303.343 " ,.. "" _ _ "4 _ 91.436 324,'940 666!l.67711991.148 736.866 II!M:1!11 324.955 666!l.600 11102.::m 729.034 f" ,'" 00.866 324.955 598!1.55811702A14 126.961 iloo 116.11111659.548 ., 1_=:1 - , . II!I.S86 324.955 6994.111312427.262 220.570 0.00 0.00 121155.855 ~_I "'I JiI --', 261S366.882 91.49C) 324.'940 6994.60012439,924 21U911 4.00 -1.31112416.583 cœ-1911(Pt1) - 2118313.126 91.239 324.941 6994.45'112444.141 208.307 iloo 17!!.II!I 1.2423.!152 _,. ! ". 2819255.S12 91.239 324.941 6635.365 13166.551 -298.431 0,00 0.00 13167.351 , 2918367210 95.701 324.933 6828.600 1325$.000 ~ iloo -0.1-1) 13261.29!1 cœ-108 (PIS) 1 'Ç 301!!16!1.436 115.161 324.933 6788.60013585.868 -5$2.413 0.00 11.00135911.579 aJ3.108(Pt9) '._ (·:11 '\ -- I '\, .< , Iii I, I 5250 I MgnH," I' I ,,: <, I ¡ :! Ii: ¡. , I ; :; I : I~~ : < ,~ Ii + ---/. I @ I , 1 ' I , ' I ' , , ,-" -, " ! ' ,- , , ,¡ J.., "I ¡: I 6000 -, .J ..! :... :..., t, __' - :.JU3-1OR (Deep M) I I ,.."" ",,, ''''' 0' 1"< '_1 ~~ CD3-108 (Pt 7) r .. 'iÍ.: I. I I II'\' "I Ii' "'" - - "" . ro~ I ; ,\ i3 í J"'U"'-'VO{Pt1) / I' 'ð: \ 10-', rWH, -- ~. ~ ~ -- ~ J- ~ - , ~ ' --' -- +- 1--1 -¡ 1- ~ -- -- __ '" [.-, ... .:::..-0 6750 ;: ~~'Fi ;~;'fii::;;_" == ::;; ;'fii:~ ¡;¡j;;:J;;j 5...::;F; "" ,;;;;!'fii:;:¡;j; -- c,; ¡::::I;;N :::::;;; ;;;; =.J=I ;P;;;:; ~ ",.~__",:- --:;;; ..... :!:::: ;:::, * w '_ ¡o.' --' _ -~_ .J 1w=1t"'''~ - \, -- -- -- -' -- '- -' -- '- -- +- -- -- - --'. r- ¡ ,- '- . 1 1 -- -: r IIIOP I " J I I ì I : J - , I I' iH7"'f 7 " ' " __~___ ._._ .~ ,_, . I""""'''''''' &/\lr!"''''''' ì ,11 ,/ I ¡ '-'~rl";' í 1 1 1 I I 1 I I 1 ¡ ¡ I I ¡ I 1 ¡ ¡ I I I 1 ¡ 1 f \ ¡ ) ¡ I I ¡ I I I I ¡ ¡ 1 I ¡ I j ¡ ì i i ¡ ì ; Iii I ¡ I i i ¡ ¡ i i ; í I ¡ ;i."t'7"~ 1 i <J) ::¡ .= WELL DETAILS: Plan: CD3-108 +iIU-S Ground level: 0.000 +fI·W Northing Eastin9 Latittude longitude 0.000 6003589,964 1528259.221 70"25'S.843N 150"54'4S.398W 8 0,000 180 Tr-avelling Cylinder Azimuth (TFO+AZI) [0] vs Centre to Centre Separation [SO Win] - Engineering Calculation Method: Minlll"Um Curvature ErrQr System: ISCWSA $can Method: Trav. Cylinder North ErrQr Surface: Sliplical Conic Warning Method: Rules Based From Colour To MD / / 36 - 300 300 40Q 40Q 500 300 750 750 1000 1 QQO 1250 1250 - 1450 1450 1750 1750 2QQO 2QQO 2500 2500 3QQO 3000 3500 3300 4000 270 4000 5000 5QQO 6000 6000 7000 7QQO 8000 8QQO - 9QQO 9000 1 ??oo 110QQO 11000 11 QQO 12000 12000 13000 13000 14000 14000 15QQO 15QQO 16000 16000 - 17000 17000 18000 18QQO 19000 19000 2QQOO ANTI-QOLUSION SETTINGS Interpolation Method: MD Interval: 25' Stations Depth Range From: 36.100 To 19769.436 Referenœ: Plan: CD3-108 (wpOO) Maximum Range: 2173.33' 90 180 Tr-avelling Cylinder Azimuth (TFO+AZI) [0] Vs Centre to Centre Separation [10 ftJin] 13500- 15000- 12000- +' J;; 1;:: 10500- ~ I J;; :5 o (J') 9000- 7500-< 6000- o 1500 3000 4500 West(-)/East(+) 6000 A HAi~UW:iitt1(Ï\~ C(}i!i..WA,,""\t Engineering Calculation MethodMinimum Curvature Error System: ISCWSA Scan Method: Horizontal Plane Error Surface: Elliptical Conic Warning Method: Rules Based ¡Iii +' "E }5 10500- ~ . "E "5 o (/) 9000- 7500- 6000- West(-)/East(+) A HALU¥it¡'H''f{i;''''- CÚ;\W/\;X'\' Engineering Calculation MethodMinimum Curvature Error System: ISCWSA Scan Method: Horizontal Plane Error Surface: Elliptical Conic Warning Method: Rules Based ¡Iii ft\;L . (; . ConocoPhillips Alaska Inc. NAD 27 Colville River Unit Alpine CD3 Plan: CD3-108 - 8 Plan: CD3-108 Plan: Plan: CD3-108 (wp06) Sperry-Sun Combo Report 02 February, 2005 Local Coordinate Origin: Viewing Datum: TVDs to System: North Reference: Unit System: Centered on Well Plan: CD3-108 - Slot 8 Doyon 19 @ 48,60011 (RKB 48.6 II above MSL) N True API - US Survey Feet OR1G1NAt- HALLIBURTON . . ConocoPhillips Alaska Inc. (Alpine) HALLIBURTON Colville River Unit Plan Report for Plan: CD3-108 - Plan: CD3-108 - Plan: CD3-108 (wp06) Measured SUb-System Vertical Local Coordinates Map Coordinates Dogleg Vertical Depth Inclination Azimuth Depth Depth +NI-S +EI-W Northing Easting Rate Section (ft) (0) (") (ft) (ft) (ft) (ft) (ft) (ft) ("/10Oft) (ft) 36,100 0,000 0.000 -12.500 36,100 0,000 0.000 6,003,842,730 388,227,339 0.00 0,000 SHL "'3931.ft FNL & 816ftFEL, Sec5·T12N·R5E 100,000 0,000 0.000 51,400 100.000 0,000 0.000 6,003,842.730 388,227.339 0.00 0.000 199,999 0.000 0.000 151.399 199.999 0,000 0.000 6,003,842,730 388,227,339 0.00 0.000 300.000 0,000 0.000 251.400 300,000 0.000 0.000 6,003,842.730 388,227,339 0,00 0.000 300,100 0.000 41.695 251.500 300.100 0,000 0.000 6,003,842.730 388,227,339 0.00 0,000 Begin Dir-3.00 DLS,30o.1MD, 300.1 TVD 400.000 3,000 41.695 351,354 399.954 1. 954 1,741 6,003,844.658 388,229,109 3,00 1.877 500,000 6,000 41.695 451.035 499.635 7,812 6.959 6,003,850.437 388,234.414 3.00 7,502 600.000 9,000 41.695 550,168 598.768 17,558 15,640 6,003,860.050 388,243.239 3,00 16.859 700,000 12.000 41,695 648.482 697.082 31,163 27.761 6,003,873.472 388,255.561 3.00 29,924 800,000 15,000 41.695 745,708 794.308 48.593 43.287 6,003,890.665 388,271,345 3,00 46.661 900.000 18.000 41,695 841,579 890.179 69.798 62.176 6,003,911.583 388,290.548 3,00 67.023 1,000,000 21,000 41.695 935,832 984,432 94.720 84,377 6,003,936,168 388,313,118 3.00 90.954 1,100.000 24.000 41.695 1,028,210 1,076.810 123,292 109.829 6,003,964.353 388,338,992 3,00 118,390 1,200,000 27.000 41.695 1,118.458 1,167,058 155,434 138.462 6,003,996.060 388,368,101 3,00 149.255 1 ,292,699 29,781 41.695 1,200,000 1,248,600 188,343 167,777 6,004,028.524 388,397,903 3,00 180,855 Base Permafrost 1,300,000 30.000 41,695 1,206,330 1,254,930 191,060 170,197 6,004,031.204 388,400.363 3,00 183.464 1,400,000 33.000 41,695 1,291.584 1,340.184 230,070 204.948 6,004,069.686 388,435.691 3.00 220.923 1,500,000 36,000 41.695 1,373,987 1 ,422.587 272,358 242,619 6,004,111.402 388,473,988 3.00 261.530 1 ,600.000 39,000 41.695 1,453,313 1,501.913 317,809 283.107 6,004,156,238 388,515,148 3,00 305,174 1,700.000 42,000 41,695 1,529,345 1,577.945 366,298 326.301 6,004,204,070 388,559,059 3.00 351.735 1,800.000 45,000 41.695 1,601,874 1,650,474 417,691 372.082 6,004,254,768 388,605.601 3.00 401.085 1,900,000 48,000 41.695 1,670.702 1,719.302 471,849 420,326 6,004,308,192 388,654,646 3,00 453.090 2,000.000 51,000 41.695 1,735,639 1,784,239 528,622 470.900 6,004,364,197 388,706.060 3.00 507.605 2,022.462 51,674 41,695 1,749.673 1,798,273 541.718 482,566 6,004,377.116 388,717,920 3,00 520.181 End Dir, Start Sail @ 51.674: 2022.4700 MD, 1798.277ft TVD 2,100,000 51.674 41,695 1,797.756 1,846,356 587.138 523,027 6,004,421,921 388,759.053 0,00 563.795 2,200.000 51,674 41.695 1,859.770 1,908,370 645.716 575.208 6,004,479,706 388,812,101 0,00 620.045 2,300,000 51.674 41,695 1,921,784 1,970,384 704,294 627.390 6,004,537.491 388,865.149 0.00 676.294 2,400,000 51.674 41,695 1,983,797 2,032,397 762,872 679,572 6,004,595,277 388,918,198 0,00 732.543 2,500.000 51,674 41.695 2,045.811 2,094.411 821.450 731,753 6,004,653.062 388,971.246 0.00 788,792 2,600.000 51.674 41,695 2,107.825 2,156.425 880.028 783,935 6,004,710.847 389,024,294 0.00 845,041 2,700,000 51.674 41.695 2,169.839 2,218.439 938.606 836,117 6,004,768.632 389,077.343 0.00 901.290 2,800,000 51.674 41,695 2,231.852 2,280.452 997.184 888,298 6,004,826.417 389,130,391 0.00 957,539 2,893,766 51,674 41.695 2,290,000 2,338.600 1,052.110 937,227 6,004,880.600 389,180.132 0,00 1,010.282 0040 2,900,000 51,674 41.695 2,293,866 2,342.466 1,055,762 940.480 6,004,884,202 389,183,439 0,00 1,013,788 3,000,000 51.674 41,695 2,355.880 2,404.480 1,114,340 992.662 6,004,941,987 389,236.488 0.00 1,070.037 3,100,000 51.674 41,695 2,417,893 2,466.493 1,172,918 1,044.843 6,004,999,772 389,289.536 0.00 1 ,126.286 3,166,933 51.674 41,695 2,459.401 2,508,001 1,212,126 1 ,079.770 6,005,038,450 389,325.043 0.00 1,163.936 9-518" Csg Pt .... Drill out 8-112" Hole: 3148.688ft MD, 2508.000n TVD - 9 518" 3,184.025 51.674 41.695 2,470,000 2,518.600 1,222,138 1,088,689 6,005,048,326 389,334.110 0.00 c..sO 3,200.000 51,674 41,695 2,479.907 2,528,507 1 ,231.496 1,097.025 6,005,057,558 389,342.585 0,00 1,182,536 3,300,000 51.674 41.695 2,541.921 2,590.521 1,290.074 1,149,207 6,005,115.343 389,395.633 0,00 1,238.785 3,400.000 51,674 41.695 2,603.934 2,652.534 1,348,652 1,201,388 6,005,173,128 389,448,681 0,00 1,295,034 3,500.000 51.674 41.695 2,665,948 2,714.548 1,407,230 1,253.570 6,005,230,913 389,501,730 0,00 1,351.283 3,600.000 51,674 41.695 2,727,962 2,776.562 1,465,808 1,305.752 6,005,288.698 389,554,778 0,00 1,407,532 3,700.000 51.674 41.695 2,789,975 2,838.575 1 ,524,386 1,357,933 6,005,346.483 389,607.826 0.00 1,463.781 3,796,793 51,674 41,695 2,850,000 2,898.600 1,581,085 1,408.441 6,005,402.415 389,659,173 0.00 1,518.226 C-20 3,800,000 51.674 41.695 2,851,989 2,900.589 1,582,963 1,410.115 6,005,404.268 389,660.875 0.00 1,520.030 3,900,000 51.674 41.695 2,914,003 2,962,603 1,641,541 1,462.297 6,005,462,053 389,713.923 0.00 1,576.279 4,000.000 51.674 41.695 2,976,016 3,024.616 1,700,119 1,514.478 6,005,519,838 389,766.971 0.00 1,632.528 4,100,000 51,674 41,695 3,038.030 3,086,630 1,758,697 1,566.660 6,005,577.624 389,820,020 0,00 1,688.778 4,200.000 51.674 41.695 3,100,044 3,148,644 1,817,275 1,618,841 6,005,635.409 389,873.068 0,00 1,745.027 02 February, 2005 . 16:41 Page 2 of 8 COMPASS ORIGINAL . . ConocoPhillips Alaska Inc. (Alpine) HALLIBURTON Colville River Unit Plan Report for Plan: CD3-108 - Plan: CD3-108 - Plan: CD3-108 (wp06) Measured Sub-5ystem Vertical Local Coordinates Map Coordinates Dogleg Vertical Depth Inclination Azimuth Depth Depth +NI-5 +EI-W Northing Easting Rate Section (It) (") (") (It) (It) (It) (It) (It) (ft) ("/10Oft) (It) 4,300,000 51.674 41.695 3,162.057 3,210.657 1 ,875,853 1,671.023 6,005,693,194 389,926,116 0.00 1,801.276 4,400,000 51,674 41.695 3,224.071 3,272.671 1,934.431 1,723,205 6,005,750.979 389,979.165 0.00 1,857,525 4,500.000 51,674 41.695 3,286.085 3,334,685 1,993.009 1,775,386 6,005,808.764 390,032.213 0.00 1,913,774 4,600,000 51,674 41.695 3,348,098 3,396.698 2,051.587 1,827.568 6,005,866,549 390,085.261 0.00 1,970.023 4,700,000 51,674 41,695 3,410.112 3,458,712 2,110,165 1,879,750 6,005,924,334 390,138.310 0.00 2,026.272 4,800.000 51.674 41,695 3,472.126 3,520,726 2,168,743 1,931.931 6,005,982,119 390,191.358 0,00 2,082.521 4,900.000 51.674 41,695 3,534,140 3,582.740 2,227,321 1,984.113 6,006,039,905 390,244,406 0.00 2,138.770 5,000,000 51.674 41,695 3,596,153 3,644.753 2,285,899 2,036,295 6,006,097.690 390,297,455 0.00 2,195.019 5,100.000 51.674 41.695 3,658,167 3,706.767 2,344,477 2,088.476 6,006,155.475 390,350.503 0.00 2,251.269 5,200.000 51.674 41,695 3,720.181 3,768.781 2,403,055 2,140.658 6,006,213.260 390,403.551 0,00 2,307.518 5,300,000 51.674 41.695 3,782.194 3,830.794 2,461,633 2,192.840 6,006,271.045 390,456.600 0,00 2,363.767 5,400,000 51.674 41.695 3,844,208 3,892.808 2,520,211 2,245,021 6,006,328.830 390,509.648 0,00 2,420.016 5,441,591 51.674 41.695 3,870.000 3,918.600 2,544.574 2,266.724 6,006,352.863 390,531.711 0,00 2,443.41 ° K-3 5,500,000 51.674 41,695 3,906,222 3,954.822 2,578.789 2,297,203 6,006,386.615 390,562,697 0.00 2,476,265 5,600,000 51,674 41,695 3,968.235 4,016,835 2,637.367 2,349,385 6,006,444.400 390,615.745 0,00 2,532,514 5,700,000 51.674 41,695 4,030.249 4,078.849 2,695.945 2,401.566 6,006,502,185 390,668.793 0.00 2,588,763 5,800,000 51.674 41,695 4,092.263 4,140,863 2,754.523 2,453,748 6,006,559,971 390,721.842 0.00 2,645,012 5,900,000 51,674 41. 695 4,154.276 4,202.876 2,813,101 2,505,930 6,006,617.756 390,774,890 0.00 2,701.261 6,000,000 51,674 41. 695 4,216,290 4,264,890 2,871.679 2,558,111 6,006,675,541 390,827.938 0,00 2,757,510 6,100,000 51,674 41,695 4,278.304 4,326,904 2,930.257 2,610,293 6,006,733.326 390,880.987 0.00 2,813.760 6,200,000 51.674 41.695 4,340.317 4,388,917 2,988,835 2,662.475 6,006,791.111 390,934,035 0.00 2,870.009 6,300.000 51,674 41,695 4,402,331 4,450,931 3,047.413 2,714.656 6,006,848,896 390,987,083 0,00 2,926.258 6,400.000 51.674 41,695 4,464,345 4,512,945 3,105,991 2,766.838 6,006,906.681 391,040.132 0,00 2,982.507 6,500.000 51.674 41,695 4,526,358 4,574.958 3,164,569 2,819.020 6,006,964,466 391,093,180 0.00 3,038.756 6,600.000 51.674 41,695 4,588,372 4,636.972 3,223,146 2,871,201 6,007,022,252 391 ,146.228 0,00 3,095.005 6,700.000 51.674 41,695 4,650.386 4,698.986 3,281,724 2,923.383 6,007,080.037 391,199.277 0,00 3,151,254 6,800,000 51.674 41.695 4,712,399 4,760,999 3,340,302 2,975,565 6,007,137.822 391,252,325 0,00 3,207.503 6,900.000 51.674 41,695 4,774.413 4,823.013 3,398,880 3,027.746 6,007,195.607 391,305.373 0,00 3,263.752 7,000,000 51.674 41,695 4,836.427 4,885.027 3,457,458 3,079,928 6,007,253.392 391,358.422 0,00 3,320,001 7,100.000 51.674 41,695 4,898.441 4,947.041 3,516,036 3,132,110 6,007,311.177 391,411.470 0,00 3,376,251 7,200,000 51,674 41.695 4,960.454 5,009.054 3,574,614 3,184,291 6,007,368.962 391,464.518 0.00 3,432,500 7,300,000 51.674 41.695 5,022.468 5,071,068 3,633,192 3,236.473 6,007,426.747 391,517.567 0,00 3,488.749 7,400,000 51.674 41.695 5,084.482 5,133.082 3,691.770 3,288.655 6,007,484.532 391,570.615 0.00 3,544,998 7,500,000 51,674 41.695 5,146.495 5,195.095 3,750.348 3,340,836 6,007,542.318 391,623.664 0,00 3,601.247 7,600,000 51.674 41.695 5,208,509 5,257,109 3,808.926 3,393.018 6,007,600.103 391,676,712 0,00 3,657.496 7,700,000 51.674 41.695 5,270.523 5,319.123 3,867.504 3,445,200 6,007,657.888 391,729.760 0,00 3,713.745 7,800,000 51.674 41.695 5,332,536 5,381.136 3,926.082 3,497.381 6,007,715,673 391,782.809 0,00 3,769.994 7,900,000 51.674 41,695 5,394,550 5,443.150 3,984,660 3,549,563 6,007,773.458 391,835,857 0,00 3,826.243 8,000,000 51.674 41.695 5,456,564 5,505,164 4,043,238 3,601.744 6,007,831,243 391,888.905 0,00 3,882.493 8,100,000 51.674 41,695 5,518,577 5,567,177 4,101.816 3,653,926 6,007,889,028 391,941,954 0,00 3,938,742 8,200.000 51,674 41,695 5,580,591 5,629.191 4,160,394 3,706.108 6,007,946.813 391,995,002 0,00 3,994,991 8,300,000 51.674 41.695 5,642.605 5,691,205 4,218,972 3,758,289 6,008,004,599 392,048,050 0,00 4,051,240 8,328,051 51.674 41.695 5,660,000 5,708,600 4,235,403 3,772.927 6,008,020,808 392,062,931 0,00 4,067.018 Albialî97 8,400.000 51,674 41,695 5,704,618 5,753.218 4,277,550 3,810.471 6,008,062,384 392,101.099 0.00 4,107.489 8,500,000 51.674 41.695 5,766,632 5,815.232 4,336,128 3,862.653 6,008,120.169 392,154.147 0.00 4,163.738 8,600,000 51.674 41.695 5,828,646 5,877.246 4,394,706 3,914.834 6,008,177.954 392,207.195 0.00 4,219.987 8,700.000 51.674 41.695 5,890,659 5,939,259 4,453,284 3,967.016 6,008,235.739 392,260.244 0.00 4,276,236 8,771,501 51.674 41,695 5,935.000 5,983.600 4,495,168 4,004.327 6,008,277,056 392,298,174 0,00 4,316.455 Albian 96 8,800,000 51.674 41,695 5,952,673 6,001,273 4,511,862 4,019.198 6,008,293.524 392,313.292 0.00 4,332.485 8,900,000 51,674 41,695 6,014,687 6,063.287 4,570,440 4,071.379 6,008,351,309 392,366.340 0.00 4,388.734 9,000,000 51.674 41,695 6,076,700 6,125.300 4,629,018 4,123.561 6,008,409,094 392,419,389 0.00 4,444.984 9,100,000 51,674 41.695 6,138,714 6,187,314 4,687,596 4,175.743 6,008,466,879 392,472,437 0,00 4,501.233 9,137,666 51.674 41.695 6,162.073 6,210.673 4,709,660 4,195.398 6,008,488,645 392,492.419 0.00 4,522.420 Begin Dlr @ 4.00 DLS: 9137.700ft MD,6210.6881t TVD 9,200,000 51,976 38.548 6,200,605 6,249,205 4,747,125 4,226.965 6,008,525,630 392,524,541 4,00 4,558.474 9,300.000 52.634 33.561 6,261.774 6,310,374 4,811,071 4,273.496 6,008,588.866 392,572.020 4,00 4,620,332 02 February, 2005 - 16:41 Page 3 of 8 COMPASS OR\G\NAL . . ConocoPhillips Alaska Inc. (Alpine) HALLIBURTON Colville River Unit Plan Report for Plan: CD3-108 - Plan: CD3-108 - Plan: CD3-108 (wp06) Measured Sub-System Vertical Local Coordinates Map Coordinates Dogleg Vertical Depth Inclination Azimuth Depth Depth +N/-S +r:J-W Northing Eastlng Rate Section (ft) e) e) (ft) (It) (ft) (ft) (ft) (ft) e/1 DOlt) (ft) 9,400.000 53,497 28,674 6,321.887 6,370.487 4,879.476 4,314,764 6,008,656.640 392,614.304 4.00 4,686.875 9,500,000 54.554 23.907 6,380,651 6,429.251 4,952.008 4,350.569 6,008,728.622 392,651,187 4,00 4,757,777 9,600,000 55,794 19.273 6,437.778 6,486.378 5,028.312 4,380.735 6,008,804,459 392,682,490 4.00 4,832.695 9,667.001 56,721 16.247 6,475.000 6,523.600 5,081.363 4,397.718 6,008,857.245 392,700.264 4.00 4,884.956 Top HRZ 9,700.000 57,203 14,783 6,492.992 6,541,592 5,108,018 4,405,117 6,008,883,784 392,708.060 4,00 4,911,263 9,800,000 58,767 10.441 6,546.022 6,594.622 5,190.736 4,423,594 6,008,966.209 392,727,772 4.00 4,993.098 9,900.000 60.471 6,246 6,596.611 6,645.211 5,276,064 4,436.077 6,009,051,334 392,741,530 4.00 5,077.801 9,925,314 60,924 5.205 6,609.000 6,657,600 5,298.029 4,438,279 6,009,073.261 392,744.060 4.01 5,099,649 BaseHRZ 10,000,000 62.303 2,195 6,644.511 6,693.111 5,363,586 4,442.506 6,009,138,742 392,749,268 4.00 5,164,960 10,014,023 62.570 1.636 6,651.000 6,699,600 5,376,010 4,442.921 6,009,151.158 392,749.869 4.01 5,177.354 K-1 10,100.000 64,249 358.282 6,689.491 6,738.091 5,452,876 4,442.848 6,009,228,009 392,750,947 4.00 5,254,150 10,108.101 64.412 357.969 6,693,000 6,741.600 5,460,174 4,442,609 6,009,235.309 392,750.818 4,02 5,261.452 Top Kuparuk D 10,200,000 66,296 354,498 6,731,330 6,779,930 5,543.499 4,437,103 6,009,318.700 392,746.580 4.00 5,344.937 10,216.710 66,648 353.876 6,738,000 6,786.600 5,558,740 4,435.551 6,009,333,962 392,745,237 4,01 5,360.232 TOp Kuparuk C 10,247.387 67.299 352,745 6,750,000 6,798,600 5,586,781 4,432.262 6,009,362,046 392,742.368 4.00 5,388.389 LCU- ~,,1 08(Pt 10) 10,300,000 68,432 350.833 6,769.824 6,818.424 5,635,012 4,425,298 6,009,410.372 392,736.128 4.00 5,436,878 10,328.063 69,047 349.823 6,780.000 6,828.600 5,660,793 4,420.904 6,009,436,214 392,732,120 4.01 5,462.826 CD3-108 (TOE) 10,400.000 70,646 347.277 6,804.787 6,853,387 5,726,971 4,407.491 6,009,502,580 392,719,701 4.00 5,529.526 10,496.440 72,846 343.938 6,835.000 6,883.600 5,815.659 4,384,713 6,009,591,591 392,698.255 4,00 5,619,121 Baae NUlqsût 10,500.000 72.927 343,817 6,836.048 6,884.648 5,818.928 4,383,768 6,009,594,873 392,697,360 3,95 5,622.428 10,600,000 75,265 340.442 6,863.454 6,912.054 5,910.433 4,354,246 6,009,686.802 392,669.213 4.00 5,715.133 10,626.283 75.889 339,566 6,870.000 6,918.600 5,934.353 4,345,541 6,009,710,848 392,660.868 4.01 CD3-108 (Pt 5) 10,668.798 76.903 338,162 6,880,000 6,928.600 5,972.893 4,330.641 6,009,749.603 392,646,548 4,00 QD3-108 (FaulO 10,700.000 77.651 337.140 6,886.872 6,935,472 6,001,042 4,319.067 6,009,777.920 392,635,398 3,99 5,807.188 10,800.000 80.076 333.898 6,906.188 6,954.788 6,090.313 4,278.404 6,009,867,782 392,596.079 4.00 5,898.146 10,900.000 82.532 330,703 6,921.307 6,969.907 6,177,811 4,232.454 6,009,955.951 392,551,448 4,00 5,987.563 11,000,000 85.010 327,545 6,932.157 6,980.757 6,263,110 4,181,441 6,010,041.997 392,501,723 4,00 6,075.004 11,009.939 85.259 327,231 6,933.000 6,981,600 6,271.452 4,176,104 6,010,050.417 392,496.511 4.02 6,083.570 Top Neehelik 11,085.356 87.139 324,866 6,938.000 6,986,600 6,333.866 4,134.080 6,010,113.448 392,455,430 4,00 6,147.755 7"CsgPt.n Begin 6-1/8" hole: H085.34Oft MD, 6986.600ft TVD - Continue 11,100,000 86.554 324.883 6,938.806 6,987.406 6,345,825 4,125,667 6,010,125,530 392,447,198 4,00 6,160.069 11,109.216 86,185 324.893 6,939.389 6,987,989 6,353.348 4,120,377 6,010,133.131 392,442.022 4.00 6,167.816 11,200.000 86.185 324.893 6,945.429 6,994.029 6,427.453 4,068.283 6,010,208,001 392,391.047 0,00 6,244,119 11,268,601 86.185 324,893 6,949.993 6,998.593 6,483.449 4,028,917 6,010,264.576 392,352,528 0.00 6,301,778 11,300,000 87.439 324,858 6,951,739 7,000,339 6,509,091 4,010,880 6,010,290,482 392,334,878 3.99 6,328.180 11,386,040 90,881 324.761 6,952.999 7,001,599 6,579.388 3,961,309 6,010,361,508 392,286.370 4.00 6,400.571 CD3-108(Deep Pt) 11,400.000 90,881 324.761 6,952.785 7,001,385 6,590.789 3,953,255 6,010,373.027 392,278.488 0.00 6,412.311 11,500,000 90,881 324.761 6,951,248 6,999.848 6,672.454 3,895.563 6,010,455,540 392,222.030 0,00 6,496.413 11,600.000 90,881 324.761 6,949.711 6,998,311 6,754.120 3,837,871 6,010,538.053 392,165.572 0,00 6,580,514 11,700.000 90.881 324.761 6,948,174 6,996.774 6,835,786 3,780,179 6,010,620.587 392,109,114 0.00 6,664,616 11,800.000 90,881 324,761 6,946,637 6,995.237 6,917.451 3,722.488 6,010,703.080 392,052.657 0.00 6,748,717 11,900.000 90,881 324.761 6,945.100 6,993.700 6,999.117 3,664,796 6,010,785.593 391,996.199 0,00 6,832.819 12,000.000 90.881 324,761 6,943,564 6,992.164 7,080.783 3,607.104 6,010,868,106 391,939.741 0.00 6,916,920 12,094,391 90.881 324,761 6,942.113 6,990.713 7,157.868 3,552.647 6,010,945.992 391,886.450 0,00 6,996.304 12,100,000 90.687 324,874 6,942.036 6,990,636 7,162.452 3,549.416 6,010,950,623 391,883,288 4.00 7,001.024 12,103,293 90,573 324.940 6,942.000 6,990.600 7,165,146 3,547,523 6,010,953.345 391,881,435 4,00 7,003.799 02 February, 2005 . 16:41 Page 4 of 8 COMPASS ORIGINAL . . ConocoPhillips Alaska Inc. (Alpine) HALLIBURTON Colville River Unit Plan Report for Plan: CD3-108 - Plan: CD3-108 - Plan: CD3-108 (wp06) Measured Sub-8ystem Vertical Local Coordinates Map Coordinates Dogleg Vertical Depth Inclination Azimuth Depth Depth +NI-8 +EJ-W Northing Easting Rate Section (ft) e) n (ft) (ft) (ft) (ft) (ft) (ft) e/1 DOlt) (ft) COO-108(Pt1) 12,145.364 90.446 323.262 6,941,626 6,990.226 7,199.223 3,522.857 6,010,987.785 391,857.284 4,00 7,038.918 12,200.000 90,446 323,262 6,941,201 6,989.801 7,243.006 3,490,177 6,011,032.048 391,825.266 0.00 7,084.083 12,300.000 90.446 323.262 6,940.423 6,989,023 7,323.142 3,430,364 6,011,113,064 391,766.664 0.00 7,166.749 12,400.000 90.446 323.262 6,939,645 6,988,245 7,403,278 3,370.550 6,011,194,080 391,708,063 0.00 7,249.414 12,500.000 90.446 323.262 6,938.868 6,987.468 7,483,414 3,310.737 6,011,275,095 391,649,461 0,00 7,332.080 12,600,000 90,446 323.262 6,938.090 6,986.690 7,563.550 3,250,924 6,011,356.111 391,590.859 0.00 7,414,746 12,700.000 90.446 323.262 6,937.312 6,985.912 7,643.686 3,191.111 6,011,437.126 391,532.258 0.00 7,497.411 12,800.000 90.446 323.262 6,936,534 6,985,134 7,723.822 3,131.297 6,011,518,142 391,473.656 0.00 7,580,077 12,817.275 90.446 323.262 6,936,400 6,985,000 7,737.665 3,120.965 6,011,532,137 391,463.533 0.00 7,594.357 12,900.000 90,695 326.560 6,935,576 6,984,176 7,805,344 3,073.421 6,011,600.515 391,417.012 4.00 7,664.043 13,000,000 90.994 330,549 6,934,100 6,982.700 7,890.633 3,021.271 6,011,686.568 391,366.150 4.00 7,751.523 13,100,000 91.289 334.541 6,932.107 6,980,707 7,979,336 2,975,187 6,011,775,943 391,321.402 4.00 7,842,149 13,104,730 91.303 334,730 6,932.000 6,980.600 7,983.609 2,973.161 6,011,780.245 391,319,441 4,00 7,846.506 C)3-1 08 (Pt 2) 13,124,707 91.270 335.529 6,931,552 6,980,152 8,001.728 2,964,762 6,011,798.487 391,311.314 4,00 7,864,974 13,200.000 91,270 335.529 6,929.883 6,978.483 8,070.241 2,933.580 6,011,867.453 391,281.165 0.00 7,934.780 13,300.000 91,270 335.529 6,927.688 6,976.268 8,161,235 2,892,167 6,011,959.049 391,241,122 0.00 8,027.493 13,400,000 91,270 335,529 6,925.452 6,974,052 8,252.230 2,850.753 6,012,050,646 391,201.079 0.00 8,120.205 13,500.000 91,270 335,529 6,923,236 6,971.836 8,343,225 2,809.339 6,012,142.242 391,161.036 0.00 8,212.917 13,600,000 91.270 335,529 6,921,020 6,969,620 8,434,219 2,767.926 6,012,233,839 391,120.993 0.00 8,305.630 13,700,000 91,270 335.529 6,918.805 6,967.405 8,525,214 2,726.512 6,012,325.436 391,080,950 0,00 8,398.342 13,800,000 91.270 335,529 6,916.589 6,965,189 8,616,208 2,685,099 6,012,417.032 391,040.907 0.00 8,491,054 13,900,000 91.270 335.529 6,914,373 6,962,973 8,707,203 2,643,685 6,012,508.629 391,000,864 0.00 8,583,766 14,000,000 91,270 335.529 6,912.157 6,960,757 8,798,197 2,602,272 6,012,600.225 390,960.821 0,00 8,676.479 14,100.000 91,270 335.529 6,909,942 6,958.542 8,889.192 2,560,858 6,012,691,822 390,920.778 0,00 8,769.191 14,200,000 91.270 335,529 6,907,726 6,956,326 8,980,186 2,519.445 6,012,783.418 390,880,735 0,00 8,861.903 14,300,000 91,270 335.529 6,905,510 6,954.110 9,071.181 2,478.031 6,012,875.015 390,840.692 0,00 8,954,616 14,400,000 91,270 335,529 6,903.295 6,951,895 9,162,175 2,436,617 6,012,966.612 390,800.649 0.00 9,047,328 14,500,000 91.270 335.529 6,901.079 6,949.679 9,253.170 2,395,204 6,013,058.208 390,760.606 0.00 9,140,040 14,600.000 91.270 335.529 6,898.863 6,947.463 9,344.165 2,353.790 6,013,149,805 390,720.563 0.00 9,232.753 14,601.002 91.270 335,529 6,898,841 6,947.441 9,345.076 2,353.375 6,013,150.722 390,720,161 0,00 9,233,681 14,700,000 91.430 331.573 6,896,508 6,945.108 9,433,669 2,309.301 6,013,239.958 390,677.422 4,00 9,324,110 14,800,000 91.585 327.575 6,893,876 6,942.476 9,519,848 2,258.683 6,013,326,878 390,628.104 4,00 9,412,413 14,865.786 91.883 324.942 6,892.000 6,940.600 9,574.525 2,222.159 6,013,382.090 390,592.406 4,00 9,488,629 CD3-108(Pt 3) 14,900.000 91.883 324.942 6,890.995 6,939.595 9,602.519 2,202,515 6,013,410.373 390,573.185 0,00 9,497,452 15,000.000 91,683 324,942 6,888.057 6,936.657 9,684.342 2,145.100 6,013,493.039 390,517.006 0.00 9,581.698 15,100.000 91,683 324,942 6,885.119 6,933,719 9,766,164 2,087,685 6,013,575,704 390,460,828 0.00 9,665.944 15,200.000 91,683 324,942 6,882,181 6,930,781 9,847,986 2,030.269 6,013,658,370 390,404,649 0,00 9,750,189 15,300.000 91.683 324,942 6,879,243 6,927.843 9,929,808 1,972.854 6,013,741,035 390,348.470 0,00 9,834.435 15,400,000 91.683 324,942 6,876,306 6,924,906 10,011,630 1,915.439 6,013,823,701 390,292.291 0.00 9,918.681 15,500,000 91,683 324,942 6,873.368 6,921,968 10,093,452 1,858.024 6,013,906.367 390,236,112 0,00 10,002,926 15,600,000 91,683 324,942 6,870.430 6,919,030 10,175,274 1,800.608 6,013,989.032 390,179.933 0,00 10,087,172 15,700,000 91.683 324.942 6,867.492 6,916.092 10,257.096 1,743.193 6,014,071.698 390,123,754 0.00 10,171.418 15,800,000 91,683 324.942 6,864.554 6,913.154 10,338.918 1,685,778 6,014,154.363 390,067.576 0.00 10,255,664 15,900.000 91,683 324.942 6,861.617 6,910.217 10,420.741 1,628,363 6,014,237.029 390,011.397 0.00 10,339,909 16,000.000 91.683 324,942 6,858,679 6,907,279 10,502,563 1,570.947 6,014,319.694 389,955,218 0,00 10,424.155 16,100.000 91.683 324,942 6,855,741 6,904,341 10,584,385 1,513.532 6,014,402.360 389,899.039 0.00 10,508,401 16,200,000 91,683 324.942 6,852,803 6,901,403 10,666,207 1,456.117 6,014,485.025 389,842,860 0,00 10,592.646 16,300.000 91.683 324.942 6,849,865 6,898.465 10,748,029 1,398,702 6,014,567.691 389,786,681 0,00 10,676.892 16,400,000 91.683 324,942 6,846,928 6,895,528 10,829.851 1,341.286 6,014,650.356 389,730,502 0.00 10,761.138 16,459.808 91.683 324.942 6,845.171 6,893.771 10,878.788 1,306,947 6,014,699.797 389,696.903 0.00 10,811.524 16,466.179 91,436 324,940 6,844,998 6,893,598 10,884,000 1,303.290 6,014,705.063 389,693.324 3.88 10,816.891 CD3-1 08 (Pt 4) 16,500,000 91,436 324.940 6,844,150 6,892.750 10,911.676 1,283.868 6,014,733.025 389,674.320 0.00 10,845.386 16,600.000 91.436 324.940 6,841,644 6,890.244 10,993,506 1,226.443 6,014,815,698 389,618.132 0.00 10,929,640 16,700.000 91,436 324,940 6,839.138 6,887,738 11,075.336 1,169.018 6,014,898,371 389,561.943 0.00 11,013.894 16,800.000 91.436 324,940 6,836.631 6,885,231 11,157.165 1,111.593 6,014,981,045 389,505,755 0,00 11,098.148 02 February, 2005 - 16:41 Page 5 of 8 COMPASS ORIGINAL . . ConocoPhillips Alaska Inc. (Alpine) HALLIBURTON Colville River Unit Plan Report for Plan: CD3-108 - Plan: CD3-108 - Plan: CD3-108 (wp06) Measured Sub-System Vertical Local Coordinates Map Coordinates Dogleg Vertical Depth Inclination Azimuth Depth Depth +NI-S +E/-W Northing Easting Rate Section (ft) CO) CO) (ft) (ft) (ft) (ft) (ft) (ft) CO /1 OUft) (ft) 16,900.000 91.436 324,940 6,834.125 6,882,725 11,238,995 1,054,168 6,015,063,718 389,449.567 0,00 11,182.401 17,000,000 91.436 324.940 6,831.619 6,880,219 11,320,825 996.743 6,015,146.391 389,393,378 0.00 11,266.655 17,100,000 91,436 324.940 6,829,113 6,877.713 11 ,402.655 939,319 6,015,229.065 389,337.190 0,00 11,350.909 17,200.000 91.436 324,940 6,826.606 6,875,206 11 ,484.484 881.894 6,015,311,738 389,281.002 0,00 11,435.162 17,300.000 91.436 324,940 6,824.100 6,872,700 11,566,314 824,469 6,015,394.411 389,224.814 0.00 11,519.416 17,400,000 91.436 324.940 6,821,594 6,870.194 11,648,144 767.044 6,015,477.085 389,168,625 0.00 11,603.670 17,452,550 91,436 324,940 6,820,277 6,868.877 11,691.145 736.867 6,015,520.529 389,139.098 0.00 11,647,945 17,466,192 90.891 324.955 6,820.000 6,868.600 11,702.311 729,034 6,015,531.810 389,131.434 4.00 1 CD3-1 De (Pt .6) 17,466,319 90.886 324,955 6,819.998 6,868,598 11,702.415 728.961 6,015,531.915 389,131,362 4.00 11,659,548 17,500.000 90.886 324.955 6,819.477 6,868.077 11,729.986 709.623 6,015,559.770 389,112.441 0.00 11,687.936 17,600.000 90,886 324.955 6,817,932 6,866.532 11,811.847 652,208 6,015,642.474 389,056.263 0,00 11,772.220 17,700,000 90,886 324,955 6,816,386 6,864,986 11,893,707 594.793 6,015,725.178 389,000,085 0.00 11,856.504 17,800.000 90.886 324.955 6,814.841 6,863,441 11,975,568 537.378 6,015,807,882 388,943.907 0.00 11,940,788 17,900.000 90,886 324.955 6,813,295 6,861.895 12,057.428 479.963 6,015,890.586 388,887.729 0.00 12,025.072 18,000.000 90.886 324.955 6,811,750 6,860,350 12,139.288 422.549 6,015,973.290 388,831.551 0.00 12,109,356 18,100.000 90,886 324,955 6,810,204 6,858.804 12,221,149 365.134 6,016,055.994 388,775,373 0,00 12,193,640 18,200,000 90,886 324,955 6,808,659 6,857,259 12,303,009 307,719 6,016,138.697 388,719.195 0.00 12,277.924 18,300,000 90,886 324.955 6,807,113 6,855.713 12,384.870 250,304 6,016,221,401 388,663.017 0.00 12,362.208 18,351,786 90.886 324.955 6,806.313 6,854.913 12,427.262 220.571 6,016,264.230 388,633.925 0.00 12,405,855 18,366.890 91.490 324,940 6,806.000 6,854,600 12,439,624 211,898 6,016,276,720 388,625.439 4.00 12,418.583 CD3408 (Pt 7) 18,373,143 91.239 324.941 6,805,851 6,854.451 12,444.741 208,307 6,016,281.889 388,621,925 4.00 12,423.852 18,400,000 91,239 324.941 6,805,270 6,853.870 12,466.720 192.884 6,016,304.095 388,606.834 0.00 12,446,481 18,500,000 91.239 324,941 6,803.107 6,851,707 12,548,557 135.455 6,016,386,775 388,550.642 0.00 12,530.742 18,600.000 91.239 324,941 6,800.944 6,849.544 12,630.393 78.026 6,016,469.456 388,494.449 0.00 12,615.003 18,700.000 91,239 324,941 6,798,781 6,847,381 12,712,230 20,597 6,016,552,136 388,438,257 0.00 12,699.264 18,800,000 91.239 324.941 6,796,618 6,845,218 12,794,067 -36.831 6,016,634,816 388,382.065 0,00 12,783,525 18,900.000 91,239 324.941 6,794.455 6,843.055 12,875.904 -94,260 6,016,717.497 388,325.873 0,00 12,867.786 19,000,000 91,239 324.941 6,792,292 6,840.892 12,957.741 -151,689 6,016,800.177 388,269.681 0.00 12,952.047 19,100,000 91.239 324,941 6,790.129 6,838.729 13,039.577 -209,118 6,016,882.858 388,213.489 0.00 13,036,308 19,200.000 91.239 324,941 6,787.966 6,836.566 13,121,414 -266.546 6,016,965.538 388,157.297 0.00 13,120.569 19,255.521 91,239 324,941 6,786,765 6,835,365 13,166,850 -298.431 6,017,011.442 388,126,099 0,00 13,167,351 19,300,000 93,015 324.938 6,785,113 6,833.713 13,203,232 -323.963 6,017,048.199 388,101.116 3.99 13,204.811 19,367,218 95,707 324.933 6,780,000 6,828,600 13,258.086 -362.465 6,017,103,619 388,063.443 4.00 13,261.290 CD3·t08(Pt8) 19,400,000 95.707 324.933 6,776,740 6,825.340 13,284.784 -381,206 6,017,130,592 388,045.106 0,00 13,288.779 19,500.000 95.707 324.933 6,766.795 6,815,395 13,366,226 -438.375 6,017,212.874 387,989,168 0,00 13,372.634 19,600.000 95,707 324.933 6,756.851 6,805.451 13,447,669 -495.544 6,017,295,156 387,933.229 0,00 13,456.490 19,700,000 95.707 324.933 6,746,906 6,795.506 13,529,111 -552,712 6,017,377.438 387,877.291 0.00 13,540,345 19,769,445 95.707 324.933 6,740,000 6,788.600 13,585.668 -592,413 6,017,434,579 387,838.445 0.00 13,598.578 Target(Tè:Ie) : 19769.4ft MD. 6788ft TVD, (904ft FNL, 4OO71t FEL, Sec29- Based upon Minimum Curvature type calculations, at a Measured Depth of 19,769,4411 the Bottom Hole Displacement is 13,598.5811 in the Direction of 357.50· (Grid), 02 February, 2005 - 16:41 Page 6 of 8 COMPASS ORIGINAL . HALLIBURTON . ConocoPhillips Alaska Inco (Alpine) Colville River Unit Plan Report for Plan: CD3-108 - Plan: CD3-108 - Plan: CD3-108 (wp06) Plan Annotations Measured Depth (ft) 36.100 300,100 2,022.470 3,166.933 9,137,700 11,085.340 19,769.430 Vertical Depth (ft) 36.100 300.100 1,798.277 2,508.001 6,210,693 6,986,599 6,788.601 Vertical Section Information 02 February, 2005 - 16:41 Angle Type TO Local Coordinates +NI-S +EI-W (ft) (ft) 0,000 0,000 0,000 0.000 541,723 482,570 1,212,126 1,079,770 4,709.679 4,195.415 6,333,853 4,134,089 13,585.656 -592.405 Target No Target (Freehand) Comment SHL -- 3931 II FNL & 81611 FEL, Sec5-T12N-R5E Begin Dir--3.oo DLS, 300.1 MD, 300.1 TVD End Dir, Slart Sail @ 51.674: 2022.47011 MD, 1798.27711 TVD 9-518' Csg PI,.. Drill out 8-1/20 Hole: 3148.68811 MD, 2508.00011 TVD Begin Dir @ 4,00 DLS: 9137.70011 MD,621 0.68811 TVD 7' Csg Pt .., Begin 6-1/8' hole: 11085.34011 MD, 6986.60011 TVD - Target (Toe) : 19769,411 MD, 678811 TVD, (90411 FNL, 400711 FEL, Sec29- Azimuth (0) Origin Type Start TVD (ft) Origin +NI_S +EI-W (ft) (ft) 357,503 Sial 0.000 0.000 36,100 Page 7 of 8 COMPASS ORIGINAL . . HALLIBURTON ConocoPhillips Alaska Inc. (Alpine) Colville River Unit North Reference Sheet for Alpine CD3 - Plan: CD3-108 - Plan: CD3-108 Coordinate System is US State Plane 1927 (Exact solution), Alaska Zone 04 using datum NAD 1927 (NADCON CONUS), ellipsoid Clarke 1866 Projection method is Transverse Mercator (Gauss-Kruger) Central Meridian is -150,00°, Longitude Origin:O.OO°, Latitude Origin:O.OO° False Easting: 500,000,00011, False Northing: 0,00011, Scale Reduction: 0.99991418 Grid Coordinates of Well: 6,003,842.730, 388,227.339 Geographical Coordinates of Well: 70° 25' 10,01' N, 150° 54' 38,02' W Grid Convergence at Surface is: -0,86° Magnetic Convergence at surface is: -25.49° ( 6 December 2004, , igrf2000) T ^ M hi agnetic hi ode!: Date: Declination: I nc linationtDip: F ¡eld strength: IGRF2000 06-D ec-04 24.63" 80.63" 57275 1 (7) Grid N orlh is 0 86" West ofTrue North (13 rid Convergence) MagneticNorth is24.63" East ofTrue Nor1h (Magnetic Dedination) Magnetic North is 25 .49" East otG rid North (Magnetic Convergence) To convert a True Direction to a 13 rid Direction, Add 0.86" To convert a Magnetic Direction to a True Direction, Add 24.63" To convert a Magnetic Direction to a Grid Direction ,Add 25.49" 02 February, 2005 - 16:41 Page 8 of 8 COMPASS ORIC31NAL . ConocJ'Phillips Database: Company: Project: Site: Well: Wellbore: Design: Casing Points formations Plan Annotations 2/2/2005 4:38:10PM EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. (Alpine) Colville River Unit Alpine COO Plan: CD3-108 Plan: CD3-108 Plan: CD3-108 (wp06) Measured Depth (ft) 3,166.932 11,085,340 19,769,430 Measured Depth (ft) 1,292,699 2,893,766 3,184,025 3,796,793 5,441.591 8,328.051 8,771.501 9,667.001 9,925.314 10,014.023 10,108,101 10,216.710 10,247,387 10,496.440 11,009.939 Measured Depth (ft) 36,100 300.100 2,022.470 3,166,933 9,137.700 11,085.340 19,769.430 SPERRY_SUN HES Planning Report Local Co-ordlnate Referenœ: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Vertical Depth (ft) 2,508,000 9 5/8" 6,986.599 7' 6,788.601 61/8" Open Hole V.rUes. Depth (ft) 1,248,600 2,338,600 2,518.600 2,898,600 3,918,600 5,708,600 5,983,600 6,523.600 6,657.600 6,699.600 6,741,600 6,786.600 6,798,600 6,883,600 6,981.600 7,111,600 Vertical Qepth (ft) 36,100 300,100 1,798.277 2,508.001 6,210,693 6,986.599 6,788.601 Base Permafrost C-40 C-30 C-20 K-3 Albian 97 Albian 96 Top HRZ Base HRZ K-1 Top Kuparuk D Top Kuparuk C LCU Base Nuiqsut Top Nechelik Base Nechelik Name Local Coordinates +NI-8 +EI-W (ft) (ft) 0.000 0,000 541.723 1,212.126 4,709,679 6,333,853 13,585.656 0,000 0.000 482.570 1,079,770 4,195.415 4,134,089 -592.405 Page 11 of 11 Name Comment . Well Plan: CD3-108 - Slot 8 Doyon 19 @ 48,600ft (RKB 48.6 ft above MSL) Doyon 19 @ 48.6ooft (RKB 48.6 ft above MSL) True Minimum Curvature 9-518 7 6-1/8 12-1/4 8-112 6-1/8 Uthology 0.00 0.00 0.00 0,00 0,00 0,00 0.00 0.00 0,00 0,00 0,00 0,00 0.00 0,00 0.00 0,00 SHL - 3931ft FNL & 816ft FEL, Sec5-T12N-R5E Begin Dir-3.00 DLS, 300,1 MD, 300,1 TVD End Dir, Start Sail @ 51.674: 2022.470ft MD, 1798,277ft TVD 9-5/8" Csg Pt ... Drill out 8-1/2" Hole: 3148.688ft MD, 2508.000ft TVD Begin Dir @ 4.00 DLS: 9137.700ft MD,6210,688ft TVD 7' Csg Pt.., Begin 6-1/8" hole: 11085,34Oft MD, 6986.600ft TVD-- Target (Toe) : 19769.4ft MD, 6788ft TVD, (904ft FNL, 4007ft FEL, Sec29- ORIGINAL COMPASS 2003, 11 Build 50 . . . '~-II" Conocur"I..IPS ConocoPhillips Alaska Inc. NAD 83 Colville River Unit AI pine CD3 Plan: CD3-108 CD3-108 Plan: CD3-108 (wp06) Travelling Cylinder Report 02 February, 2005 RIGINAL . Conoc;p.,illips . SPERRY_SUN HES Anticollision Report Company: Project: Reference Site: Site Error: Reference Well: Well Error: Reference Wellbore Reference Design: Reference ConocoPhillips Alaska Inc. NAD 83 Colville River Unit Alpine CD3 0.0001t Plan: COO-108 0.0001t CD3-108 Plan: CD3-108 (wp06) Plan: CD3-108 (wp06) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well Plan: CD3-108 - Slot 8 RKB Doyon 19 @ 48,6001t (48.6 It above MSL) RKB Doyon 19 @ 48.6001t (48.6 It above MSL) True Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset Datum Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.0001t Error Model: Depth Range: Unlimited Scan Method: Results Limited by: Maximum center-center distance of 2,173.3341t Error Surface: Warning Levels evaluated at: 0.00 Sigma ISCWSA Trav, Cylinder North Elliptical Conic Date 212/2005 TO' (ft) $urvey (WellbOl'e) 36,100 19,769,436 Plan: CD3-108 (wp06) (CD3-108) Tool Name MWD MW D - Standard Reference Offset Centre to' Measured Measured Centre Si~~ Depth Depth Dlstalic. OffsetW.II" WtfIÞore-t)e$tgn (ft) (ft) (ft) Alpine COO Plan: CD3-106 - Plan CD3-106 - Plan: CD3-106 (wp 249,994 250,000 40.634 4.64 35,991 Pass - Major Risk Pian: CD3-107 - Plan: CD3-107 - Plan: CD3-107 (wp 249,994 250,000 20.599 4,64 15.956 Pass - Major Risk Plan: COO-109 - Plan: CD3-109 - Plan CD3-109 (wp 324,784 325,000 20,138 5,29 14.850 Pass - Major Risk Plan: CD3-110 - Plan: CD3-110 - Plan: CD3-110 (wp 472.002 475,000 41,525 8.85 32,693 Pass - Major Risk Plan: CD3-111 - Plan: COO-111 - Plan: CD3-111 (wp 324.367 325,000 60.130 5,28 54.847 Pass - Major Risk Plan: CD3-112 - Plan: CD3-112 - Plan: CD3-112 (wp 324,164 325,000 80,131 5.28 74,851 Pass - Major Risk Plan: CD3-113 - Plan: CD3-113 - Plan: CD3-113 (wp 323,964 325,000 100,142 5.28 94.864 Pass - Major Risk Plan: CD3-114 - Plan: CD3-114 - Pian: CD3-114 (wp 323,767 325.000 120,133 5,28 114,858 Pass - Major Risk Plan: CD3-115 - Plan: CD3-115 - Plan: CD3-115 (wp 323.574 325.000 140,132 5,27 134.859 Pass - Major Risk Plan: CD3-116 - Plan: CD3-116 - Plan: CD3-116 (wp 224.999 225.000 160,166 3.71 156.459 Pass - Major Risk Plan: CD3-117 - Plan: CD3-117 - Plan: CD3-117 (wp 224,999 225,000 180,179 3.67 176.512 Pass - Major Risk Plan: CD3-301 - Plan: CD3-301 - Plan: CD3-301 (wp 1 ,159.234 1,125,000 76.572 10,03 69.021 Pass - Major Risk Plan: CD3-302 - Plan: CD3-302 - Plan: CD3-302 (wp 1,090,870 1,075.000 71.048 23.35 47,707 Pass - Major Risk Plan: CD3-303 - Plan: CD3-303 - Plan: CD3-303 (wp 249,994 250,000 100.562 4.64 95,919 Pass - Major Risk Plan: CD3-304 - Plan: CD3-304 - Plan: CD3-304 (wp 506.461 499.998 80,911 9.46 71,486 Pass - Major Risk Plan: CD3-305 - Plan: CD3-305 - Plan: CD3-305 (wp 236.097 199.999 60.256 4,28 55.979 Pass - Major Risk Alpine Satellites Fjord 5 - Fjord 5 - Fjord 5 13,642.395 7,025.000 937,697 309.58 635,372 Pass - Major Risk Fjord 5 - Fjorid 5 PB1 - Fjorid 5 PB1 13,735,869 7,000,000 820.554 316.90 510.956 Pass - Major Risk 2/2/2005 1:47:22PM CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation Page 2 of 105 COMPASS 2003. 11 Build 50 (1 n t G···. 'N'· I A' ì",) f'\ @] t ¡' /! ~ L_ . ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 . ~ ConocoPhillips February 28, 2005 Alaska Oil and Gas Conservation Commission 333 West ¡th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED MAR 01 2005 Dear Sir or Madam: Alaska 0;1 & GII Cons. CommissiQI'! ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore injector w~rfMfAlWte Fiord CD3 drilling pad. The intended spud date for this well is 3/15/2005. It is intended that Doyon Rig 19 be used to drill the well. Re: Application for Permit to Drill CD3-108 CD3-108 will be drilled to penetrate the Nechelik reservoir horizontally. After setting 7" intermediate casing, the horizontal section will be drilled and the well completed as an open hole injector. At the end of the work program, the well will be closed in awaiting completion of well work and facilities construction that will allow the well to begin injection fourth quarter 2006. It is also requested that the packer placement requirement be relaxed to place the completion packer 300 ft TVD above the Nechelik formation. This will place the completion at a maximum inclination less than "65° and allow access to the completion with standard wireline tools for future intervention. 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. Fee of $1 00 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program. 4. A proposed completion diagram. 5. A drilling fluids program summary. 6. Pressure information as required by 20 ACC 25.035 (d)(2). 7. 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 layout as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of diverter set up. If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. ~? Vern Johnson Drilling Engineer :Zp'D/o~ . Attachments cc: CD3-108 Well File / Sharon Allsup Drake Chip Alvord Vern Johnson Jack Walker Jordan Wiess Lanston Chin . ATO 1530 ATO 1700 ATO 1702 ATO 1740 ATO-1782 Kuukpik Corporation e, SHARON K. ALLSUP-DRAKE 1 094 CONOCOPHILLlPS ~ob~1~~O DATE 1 H.4-rd.. ZlKP.Ç 62-14/311 ANCHORAGE AK 99501 ~~1~~6~E5!/frft)p;It~tJ4f IACGCC I $/CO.OO ---OJ<¿ ~ J~ !!t"v9 /tJ rvA-CirJ[:.fs~flJ--~~~::::' .~ CHAse ;,::=::,:~.::.~~:". v.~§[~oOn~4- I: 0 ;j ~ ~ 0 0 ~ a.. a.. I : 2 ~ B a.. 7 ~., 0 7., 2 7 b III ~ 0 ., a.. I _c""_'jM!l!'\m.",,,,..,,,,;\."_,...,,.',..ð",,''''''''''''''''''''='~1'lilff1_''''',,,,"...·__. .H.',;<-lili"·"""_"';',.u""'~i."_,_"JI:,,".,\,,..~'!$."~^~"""".'·'~"".. "~ ".-",;.._"".,~!.\I!I!""""',",," . «..,,_;."',.(,.,'"~_.\ ,._;".~.'~:." ,";,.."_",,,,,;...c,,,';""¡""_,,",,,,,''''",,.~,.,,,,_,,,,.·,~.,·.. ..... ,~""'.~ """'''¡''''~'''''''''''',_.f'>''_''''_'''''''~~_~';'~';jf.~~~'''\.;'';!!i¡' . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAMEr~à r:{).~ - /O~ PTD# 2dS-a,"~,,~ Development X Service CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If APJ number last two, (2) digits are between 60-69) Exploration Stratigraphic "CLUE"· Tbe permit is for a Dew weUbore segmeDt of e:listiDg weD'. . Permit No, " API No. . Production. sbould cODtinue to be reponed as a fUDctioD' of tbe origiDal API Dumber. stated a))ove. . HOLE )D accordaDce witb' ZO AAC 25.005(1), an records, data and logs acquired for tbe pilot bole must be clearly differeDtiated ìD botb Dame (name OD permit plus PH) aDd APJ Dumber (50 70/80) from records, data aDd logs acquired for we)) (Dame OD permit). Pß.,OT (PH) SPACING EXCEPTION x' DRY DITCH SAMPLE The permit is approved subject ·to fuD compliaDce with 20 AAC 25~055~ Approval to perforate aDd produce is cODtingeDt upon issuance of ~ cODservation order approviDg a spacing' e~ceptioD. (Company Name) assumes tbe JiabiUty of aDY protest to tbe spaciog ,~JCeptioD tbat lD'y occur. AU dry ditcb sample sets submitted to tbe Commission must be ip DO greater 1baD 30' sample iDterva)s from below tbe perm.frost or from where samples are lint caugbt aDd ] 0' samplebitervals tbrough target 7.0Des. Field & Pool COLVILLE RIVER - 120000 Well Name: COLVILLE RIV UNIT CD3-108 Program SER Well bore seg D PTD#: 2050330 Company CONOCOPHILLlPS ALASKA INC Initial Classffype SER 11WINJ GeoArea Unit On/Off Shore On Annular Disposal D Administration 1 _P~rmit fee attachep _ _ _ _ _ _ . . .. Yes - - - - ~ - - - - - - - - - - - - - - - - - 2 .Leas~_numberappropriate. . . . . . . . . Y~s - - - - - - - - - " . - - - 3 .U.nlque weltnam~.and Ol!mb.er . . . . . . . . . . . _ . . . . . . .Y~s - - - - - - - - - + - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - + - - - - - - -- 4 Well Jocat~d In.a d.efioep pooL .. No. This is th~first welUrom the CD3 pad, TheßccumuJatioo is called Hord, 00 sp~cifiç pooL code exjsts. forth. 5 Well .located proper .distance. from driJling uoitbouod.ary. .. Yes ac_cumulation.. . - - - - - - - - - - - - - - - - 6 WeJlJocated pr_oper _distance. from otber welJs. . Y~s - - - - - - - - - - - - - - - - - - - - - 7 Sj.tficieotacreage.ayailable lndrilJiog unit. · . Y~s - - - - - 8 Jfd~viated. js weJlbore platiocJu.ded . . . .. Yes - - - - - - - - - - - - - 9 Operator ooly affected party. . - - - - - - - · . No. - - - - - - - - - - - - - - - - - - - - - - - - - 10 .Oper_ator bas..approprlate.Qond inJorce . . . . . . . . . . ........ Y~s - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 11 P~rmit çan be issued wjtbout conservatioo order. . . _ .. No. 80 810. n.eeds. to be written 166 does -"OtiocJude thjs. area., Tbe. existiog CRU CO .sbould aJsobeupdated.lo . Appr Date 12 P~rmit c.an be issued witbout ad.mioistratÌ\le.approval . ..... Yes includ.e.tbis açcumulation. . . . . . . . . . . . . . . . . - - - - - - - - - - - - RPC 3/2/2005 13 Can permit be approved before 15-day wait No 14 Well .located withio area alldstrata .authorized by.lnjectioo Ord~r # (put 10# in_ comments). (For. No. This injectoris exte.maJ to .tbe. AIO J 66 affected .area. . . - - - - - - - - - - - - - 15 .A)lwel!s.within.1l4.mite.area.ofreYiewid~0t[fied(Forservj~.we!looly)............... Y~s fiord .5.( 19.9:020), . . _ _ _ . . . . . . . . _ . _ _ . . . . . . . . . . _ _ _ _ . . . . . . . . . . . . . . . - - . . . . 16 Pre-produced. injector: puration.of pre-propuctioo I~ss than 3 months. (For_service well only) . . .NA - - - - - - - - - - - - - ~ - - - - - - - - - - - 17 ACMPJ:il1ding.of CQn.sistency_has been issued. for.tbis proiect . . . . . . . · .NA - - - - - - - - - - Engineering 18 Cooductor string.provided _ . - - - - - - - - · . Y~s - - - - - - - - - - - - - - - - - - - - - - - 19 .S.urfa~ .casing. pJoteçts. alLknown USDWs . - - - - - - - - - . NA lQ fresh water bas been iden.tified.ilJ CRU,. Cas.in-9.d~pth plaonep.as inAlpioe., _ . 20 .CMT. vol adequate to circ.utate. on .cood_uctor 8. surf csg . .. Yes - - - - - - - - - - - - - - - - - - -- - - - - - - - - 21 .CMT. v.ot adeQu_ate to tie-in Jong .striog to.surf cs.g . - - - - - - ~ No 811 hydr_ocarbQns will be .cov.ere_d, AnouJaJ dispo.s<ll.may .be p(oposed.. . . . _ _ 22 CMTwill coYer.aJlkoown.pro_duc;tiYe bQri¡!:ons .. No. Open hoLe .completion planoed, . . . . _ _ - - - - - - - - - - - - - - - 23 C.asiog designs adeQuate fo( C. T~ B& perroafr.ost - - - - - - · . Yes - - ~ - 124 Apequatetankage.oJ re_serye pit. .. Yes Rig jsequippe.d.witb st~el.pjts, NQ reseJ',"e_pjtplaOlJed, AJI w<lste to.Class JLwell.. . . . 25 Jfare-drill~ basa 100403 for abandonment be~o apPJQved . · .NA - - - - - - - - - - - - 26 .ApequateweJlbore. separation.proposed. . . . _ . _ _ . . . . . . . . . . . . . . - . . . . . .Y~s I?rO'5imity analysis perf.orme.d, O.nly _ctose approach. is e'5pJoratioo welt F:iQrd 5 aod. 1?6 t - - - - - - - - - 27 J(djverter required, does jt meet reguJatioos. _. Yes - - - - - - - - - - - - - - - - - - - - - .- Appr Date 28 .Dri[liog fJujdprogram sçhematic.& equipJistadequate. - - - - _ _ Y~s Maximum expected BHP 6.7EMWMW.pJanoed.9.6 -9.,8 in 8:1/2" hole alJd.9..0 - 9.,3 in.zOlJe.s. . TEM 3/2/2005 29 .BOP.Es..do .they meet reguJatiolJ . - - - - - - · . Y~s - - - - - - - - - - - - - - - - - - tR-~ 30 BOP.Epre.ss ratiog appropriate; .test to _(pu.t psig in .commeots) .. Y~s M8$1=' calcuJate.d.at 2462 pst 35QOp-si.approprjate.CPAJ plans.tO testto 50QOpst . . . . 31 Choke manifold compJies w/API RP-53 (May 64) - - - - .. Y~s - - - - - - - - - - - - - - - - - - - - - - - - - - 32 Work will oCC.U( withQYtoperatjonsbutdown. - - - - - - - - .. Y~s When driJliog is completed. welJ wiJl !ikeJynot produce uotil 1 Q 2006, . . . . . . . . 33 .Is. presence. of H2$ gas probable. . . . . . No_ tl2S was. not report.ed in.tbe expLo(ation. wells.. Rig js_e_quipped.witb sensors aod alarms.. . - - - - 34 MecbanicaLcolJdition of wells withio 80R yerified. (for_s_ervi~ welJ onJyj. .. Y~s Ooly penetratioos io AORare. F:iQrd 5 aod -.5PB1.. F:ile reviewjodjcates botb penetratioos plugged properly, Geology 35 P~rmil c.an be issu.ed w/o hydrogen s.ulfide meaS.Ures . .. Y~s first wellon.lhis pa_d, cuttings an.d.mu.dJogJequjred. Potential drilling hazards are. described in th~dril!io 36 _D_ata. preseoted on pote.ntial oveJpres.sure .zooes. . - - - - - · _ No. program. Adja.cent welJ control jn.dicates 00 ab.normal c;onditions..h.owev.er PQtential.drilling_ Appr Date 37 S~ismican<llysjs. of sballow gas_zooes. . .. No. baz<lrds and mitigation mea.sures <Ire jd.entified,.RP.C. - - - - - - - - - - RPC 3/2/2005 38 S~abedcoodjtioo survey.(if off-shore) . _ . . . . · .NA . . . 39 _ Conta_ctl1amelphoneJQr.weekly progress_reports [exploratory _ooly] · .NA Geologic Date: Engineering Date ~ Date Commissioner Commissioner m . ner J5T~ 3 } 2-1 è -r-raJ . . 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 fìnding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . Sperry-Sun Drilling Services LIS Scan Utility . :<05"-o"??? $Revision: 3 $ LisLib $Revision: 4 $ Thu Apr 28 15:14:25 2005 #~ Reel Header Service name.... . . . . . . . . .LISTPE Date. . . . . . :'. . . . . . . . . . . . . .05/04/28 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. . . . . . . . . . . . . . . . . . . . .05/04/28 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 (Fiord) MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA CD3-108 501032050700 ConocoPhillips Alaska, Inc. Sperry Drilling Services 28-APR-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003591167 M. HANIK D. BURLEY MWD RUN 2 MW0003591167 R. KRELL L. HILL MWD RUN 3 MW0003591167 R. KRELL D. MICKEY # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 5 12N 5E 3931 816 49.60 13.00 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 12.250 8.500 6.125 CASING SIZE (IN) 16.000 9.625 7.000 DRILLERS DEPTH (FT) 114.0 3075.0 11075.0 # 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 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), AND ACOUSTIC CALIPER (ACAL). 4. MWD RUN 2 COMPRISED DIRECTIONAL, DGR, EWR4, CTN, ACAL, STABILIZED LITHO- DENSITY (SLD), PRESSURE WHILE DRILLING (PWD), AND GEOPILOT ROTARY-STEERABLE BHA (GP). 5. MWD RUN 3 COMPRISED DIRECTIONAL, DGR, EWR4, PWD, GP, AND AT-BIT INCLINATION (ABI). MAD PASS DATA WERE ACQUIRED OVER THE INTERVAL 15357'MD-1479S'MD (BIT DEPTHS) WHILE POOH AFTER REACHING TD . THESE DATA ARE DISPLAYED SEPARATELY IN THIS PRESENTATION. 6. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILLSITE 3 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 7. MWD RUNS 1 - 3 REPRESENT WELL CD3-10S WITH API#: 50-103-20507-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF lS915'MD/6S16'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, ACAL-DERIVED). CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING BIT-TO-SENSOR DISTANCES. . . PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: ACAL-DERIVED (12.25" & 8.5" BITS) MUD WEIGHT: 8.7 - 10.00 PPG MUD SALINITY: 200 - 1000 PPM CHLORIDES FORMATION WATER SALINITY: 25000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name.. .......... .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/04/28 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE ROP NPHI FCNT NCNT RHOB DRHO PEF RPM RPD RPS RPX FET GR $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 115.5 116.5 116.5 116.5 133.0 133.0 133.0 167.5 167.5 167.5 167.5 167.5 175.5 STOP DEPTH 18915.0 10998.5 10998.5 10998.5 11012.5 11012.5 11012.5 18864.5 18864.5 18864.5 18864.5 18864.5 18857.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: BIT RUN NO 1 2 3 MERGED MAIN PASS. $ MERGE TOP 115.5 3085.0 11085.0 MERGE BASE 3085.0 11085.0 18915.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. ..... ......... ..Down Optical log depth units......... ..Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined . . Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 115.5 18915 9515.25 37600 115.5 18915 ROP MWD FT/H 0.81 2136.82 146.614 37600 115.5 18915 GR MWD API 11.55 420.51 86.5197 37365 175.5 18857.5 RPX MWD OHMM 0.14 2000 8.85307 37395 167.5 18864.5 RPS MWD OHMM 0.1 2000 11.0826 37395 167.5 18864.5 RPM MWD OHMM 0.08 2000 13.9179 37395 167.5 18864.5 RPD MWD OHMM 0.12 2000 17.8226 37395 167.5 18864.5 FET MWD HOUR 0.16 96.65 1. 0709 37395 167.5 18864.5 NPHI MWD PU-S 8.52 107.11 35.7764 21744 116.5 10998.5 FCNT MWD CNTS 510.35 3428.92 1007.43 21744 116.5 10998.5 NCNT MWD CNTS 106930 213784 141006 21744 116.5 10998.5 RHOB MWD G/CM 1.092 3.866 2.27933 21679 133 11012.5 DRHO MWD G/CM -0.931 1. 279 0.057555 21679 133 11012.5 PEF MWD BARN 0.24 13 .46 2.58035 21760 133 11012.5 First Reading For Entire File...... ... .115.5 Last Reading For Entire File.......... .18915 File Trailer Service name. ........... .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/04/28 Maximum Physical Record. .65535 File Type............ ... .LO Next File Name......... ..STSLIB.002 Physical EOF File Header Service name. ........... .STSLIB.002 Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation...... .05/04/28 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER . . FILE NUMBER: EDITED MERGED MAD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE SGRC SEXP SFXE SEDP SESP SEMP SRAT $ 2 and clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH 14740.0 14747.0 14747.0 14747.0 14747.0 14747.0 14798.0 STOP DEPTH 15298.5 15305.5 15305.5 15305.5 15305.5 15305.5 15356.5 # MERGED DATA SOURCE PBU TOOL CODE $ MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE # REMARKS: MERGED MAD PASS. $ # Data Format Specification Record Data Record Type....... ......... ..0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units....... ....Feet Data Reference Point... ... ...... ..Undefined Frame Spacing.................... .60 .1IN Max frames per record........... ..Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 14740 15356.5 15048.3 1234 14740 15356.5 RAT MAD FT/H 8 991 424.286 1118 14798 15356.5 GR MAD API 44.31 91.1 68.0783 1118 14740 15298.5 RPX MAD OHMM 3.68 6.42 4.93667 1118 14747 15305.5 RPS MAD OHMM 4.7 8.2 6.35776 1118 14747 15305.5 RPM MAD OHMM 5.87 11. 19 7.55843 1118 14747 15305.5 RPD MAD OHMM 6.93 13 .36 8.918 1118 14747 15305.5 FET MAD HOUR 87.77 97.66 92.5478 1118 14747 15305.5 First Reading For Entire File......... .14740 Last Reading For Entire File..... ..... .15356.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.... ...05/04/28 . Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number..... ......1.0.0 Date of Generation. .... ..05/04/28 Maximum Physical Record..65535 File Type.............. ..LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP NCNT FCNT NPHI PEF DRHO RHOB RPX FET RPD RPS RPM GR $ 3 . header data for each bit run in separate files. 1 .5000 START DEPTH 115.5 116.5 116.5 116.5 133.0 133.0 133.0 167.5 167.5 167.5 167.5 167.5 175.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 3085.0 2980.5 2980.5 2980.5 3000.0 3000.0 3000.0 3033.0 3033.0 3033.0 3033.0 3033.0 3041. 0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CTN ASLD $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 COMP THERMAL NEUTRON Azimuthal Litho-Den # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # 24-MAR-05 Insite 68.18 Memory 3085.0 115.0 3085.0 1.0 53.9 TOOL NUMBER 053516 81797 10507509 727402 12.250 114.0 . BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type. .................0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.. ... ... ...Feet Data Reference Point... ......... ..Undefined Frame Spacing.................... .60 .1IN Max frames per record.......... ...Undefined Absent value....... ............. ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . Spud Mud 9.60 300.0 8.9 1000 9.8 2.800 2.150 2.600 3.000 66.0 88.0 66.0 66.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 NPHI MWD010 PU-S 4 1 68 32 9 FCNT MWD010 CNTS 4 1 68 36 10 NCNT MWD010 CNTS 4 1 68 40 11 RHOB MWD010 G/CM 4 1 68 44 12 DRHO MWD010 G/CM 4 1 68 48 13 PEF MWD010 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 115.5 3085 1600.25 5940 115.5 3085 ROP MWD010 FT/H 1. 88 2136.82 213.815 5940 115.5 3085 GR MWD010 API 11. 55 214.86 87.15 5732 175.5 3041 RPX MWD010 OHMM 0.43 2000 14.4797 5732 167.5 3033 RPS MWD010 OHMM 0.1 745.65 23.5791 5732 167.5 3033 RPM MWD010 OHMM 0.08 2000 34.6514 5732 167.5 3033 RPD MWD010 OHMM 0.12 2000 35.6235 5732 167.5 3033 FET MWD010 HOUR 0.16 4.13 0.525073 5732 167.5 3033 NPHI MWD010 PU-S 8.52 107.11 46.31 5729 116.5 2980.5 FCNT MWD010 CNTS 510.35 2068.57 820.911 5729 116.5 2980.5 NCNT MWD010 CNTS 124067 213784 153420 5729 116.5 2980.5 RHOB MWD010 G/CM 1.092 3.866 1.96586 5735 133 3000 DRHO MWD010 G/CM PEF MWD010 BARN . -0.191 0.24 1. 279 9.67 0.0857902 5735 1.85734 5735 First Reading For Entire File......... .115.5 Last Reading For Entire File.......... .3085 File Trailer Service name........... ..STSLIB.003 Service Sub Level Name... Version Number;... ..... ..1.0.0 Date of Generation...... .05/04/28 Maximum Physical Record. .65535 File Type............... .LO Next File Name....... ....STSLIB.004 Physical EOF File Header Service name...... .......STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/04/28 Maximum Physical Record..65535 File Type.............. ..LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NPHI FCNT NCNT PEF DRHO RHOB RPS RPD FET RPX RPM GR ROP $ 4 . header data for each bit run in separate files. 2 .5000 START DEPTH 2991. 5 2991. 5 2991. 5 3000.5 3000.5 3000.5 3033.5 3033.5 3033.5 3033.5 3033.5 3041. 5 3085.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10998.5 10998.5 10998.5 11012.5 11012.5 11012.5 11042.5 11042.5 11042.5 11042.5 11042.5 11050.0 11085.0 29-MAR-05 Insite 66.37 Memory 11085.0 3085.0 11085.0 49.1 84.6 133 133 3000 3000 # . TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CTN $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type. . . . . . . . . . . . . . . . . .0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point. .......... ...Undefined Frame Spacing....... ........ ......60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . ; . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 . TOOL NUMBER 124725 134758 78609 185457 8.500 3075.0 LSND/Glydril 10.00 42.0 9.0 500 3.0 1.500 .650 1. 350 2.600 66.0 160.0 66.0 66.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 NPHI MWD020 PU-S 4 1 68 32 9 FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 G/CM 4 1 68 44 12 DRHO MWD020 G/CM 4 1 68 48 13 PEF MWD020 BARN 4 1 68 52 14 First Last .. . .ding Name Service Unit Min Max Mean Nsam Reading DEPT FT 2991. 5 11085 7038.25 16188 2991.5 11085 ROP MWD020 FT/H 10.92 547.97 182.865 16000 3085.5 11085 GR MWD020 API 41.49 420.51 115.224 16018 3041. 5 11050 RPX MWD020 OHMM 0.45 2000 5.13609 16019 3033.5 11042.5 RPS MWD020 OHMM 0.38 2000 5.20656 16019 3033.5 11042.5 RPM MWD020 OHMM 0.2 340.55 5.24803 16019 3033.5 11042.5 RPD MWD020 OHMM 0.17 2000 10.2531 16019 3033.5 11042.5 FET MWD020 HOUR 0.16 72 .14 0.852473 16019 3033.5 11042.5 NPHI MWD020 PU-S 9.57 59.09 32.0083 16015 2991.5 10998.5 FCNT MWD020 CNTS 522.99 3428.92 1074.15 16015 2991. 5 10998.5 NCNT MWD020 CNTS 106930 195372 136565 16015 2991. 5 10998.5 RHOB MWD020 G/CM 1.284 2.972 2.39209 15944 3000.5 11012.5 DRHO MWD020 G/CM -0.931 0.218 0.047399 15944 3000.5 11012.5 PEF MWD020 BARN 1. 32 13.46 2.8391 16025 3000.5 11012.5 First Reading For Entire File......... .2991.5 Last Reading For Entire File.......... .11085 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .05/04/28 Maximum Physical Record. .65535 File Type.............. ..LO Next File Name...... .... .STSLIB.005 Physical EOF File Header Service name........... ..STSLIB.005 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/04/28 Maximum Physical Record. .65535 File Type.......... ......LO Previous File Name. .... ..STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 5 header data for each bit run in separate files. 3 .5000 START DEPTH 11043.0 11043.0 11043.0 11043.0 11043.0 11050.5 11085.5 STOP DEPTH 18864.5 18864.5 18864.5 18864.5 18864.5 18857.5 18915.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : 09-APR-05 Insite 66.37 Memory .. . TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.. ...0 Logging Direction...... ......... ..Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record... ....... ...Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 18915.0 11085.0 18915.0 . 86.6 104.9 TOOL NUMBER 135134 73764 6.125 11075.0 Flo-Pro 9.10 49.0 8.6 35000 3.6 NT 2.000 .860 1.800 3.200 72.0 176.0 72.0 72.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 Name Service Unit Min Max Mean Nsam First Reading Last Reading ... \ .. . .11043 DEPT FT 11043 18915 14979 15745 18915 ROP MWD030 FT/H 0.81 226 84.0858 15660 11085.5 18915 GR MWD030 API 31.46 162.36 56.8428 15615 11050.5 18857.5 RPX MWD030 OHMM 0.14 1343.56 10.5975 15644 11043 18864.5 RPS MWD030 OHMM 0.17 1344.52 12.5207 15644 11043 18864.5 RPM MWD030 OHMM 3.69 1936.66 15.1989 15644 11043 18864.5 RPD MWD030 OHMM 3.94 2000 19.0512 15644 11043 18864.5 FET MWD030 HOUR 0.4 96.65 1. 49456 15644 11043 18864.5 First Reading For Entire File......... .11043 Last Reading For Entire File..... ..... .18915 File Trailer Service name............ .STSLIB.005 service Sub Level Name... Version Number........ ...1.0.0 Date of Generation. ......05/04/28 Maximum Physical Record..65535 File Type.. ... .......... .LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name..;........ ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/04/28 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.............. ..UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments........... ..... .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/04/28 Origin.................. .STS Reel Name....... ....... ..UNKNOWN Continuation Number.... ..01 Next Reel Name.......... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File