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Home My WebLink About207-052P~ect Well Histo File Cov~er Pa e Image ~ ry J XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q ~- D~~ Well History File Identifier Organizing (done) ^ Two-sided (I I II II II I~ II I II III ^ Rescan Needed III (I'IIIIIII (IIIII RE AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: DIGITAL DATA Diskettes, No. ` ^ Other, No/Type: OV SIZED (Scannable) Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: BY: Maria Date: ~ ^ Other:: /s/ Pro'ect Proofin I g III IIIIII (I IU I I(II BY: Maria Date: 3 D ~S~ i ~ x 30 =~~ + ~= ~~ TOTAL PAGES~ on Scanning Preparat ,_ „ Q (Count does not inGude cover sheet) BY: Maria Date: ~ ~' /~~ ~ ~S~ Production Scanning ""'•""• "' " Stage 1 Page Count from Scanned File: ~(Count does +nclude cover heet) Pa e Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: 3 ~ ~a /s/ ~ ~ J ~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: Scanning is complete at this point unless rescanning is required. /s/ I~I III~~IIII~ ~~I~I ReScanned II I II II II (I III ( I III BY: Maria Date: ~S~ Comments about this file: Quality Checked III ~I~II~ (II I~II ~I~ 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA RECEIVED A•KA OIL AND GAS CONSERVATION CaISSION REPORT OF SUNDRY WELL OPERATIONS JUL 16 216125 • 1. Operations Performed: AcJGC1.r ❑Abandon ❑Repair Well ❑Plug Perforations ❑Perforate ❑Re-Enter Suspended Well ❑Alter Casing ❑Pull Tubing ❑Stimulate-Frac ❑Waiver ®Other ❑Change Approved Program ❑Operation Shutdown ❑Stimulate-Other ❑Time Extension Pull PCP Rotor&Corod 1 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration(Alaska)Inc. ❑Exploratory ❑Stratigraphic 207-052 ' 3. Address: ®Development ❑Service 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 50.029-23355-00-00' 7. Property Designation(Lease Number): 8. Well Name and Number: ADL 380109&380110 MPS-37 . 9. Logs(list logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Milne Point Unit/Ugnu 11. Present well condition summary: Total depth: measured 4814' feet• Plugs:(measured) None feet true vertical 4385' feet Junk:(measured) 3552' feet ■ Effective depth: measured 4380' feet Packer: (measured) None feet true vertical 3978' feet Packer: (true vertical) None feet Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 20" 115' 115' 1490 470 Surface 3822' 9-5/8" 35'-3857' 35'-3487' 5750 3090 Intermediate Production 4761' 7" 33'-4794' 33'-4366' 7240 5410 Liner SCANNED NOV 6 6 2013 Perforation Depth: Measured Depth: 4260'-4275' feet k True Vertical Depth: 3865'-3879' feet Tubing(size,grade,measured and true vertical depth): 4-1/2", 12.6#x 3-1/2",9.3# L-80 4280' 3884' Packers and SSSV(type,measured and true vertical depth): None None None 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment description 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: 0 0 0 60 0 Subsequent to operation: 0 0 0 60 0 14.Attachments: ❑Copies of Logs and Surveys run 15.Well Class after work: ❑Exploratory ❑Stratigraphic ®Development ❑Service ®Daily Report of Well Operations 16. Well Status after work: • Oil ❑Gas ❑WDSPL 121 Well Schematic Diagram ❑GSTOR ❑WINJ ❑WAG ❑GINJ ❑SUSP ❑SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact: Aras Worthington,564-4102 313-231 Email:Aras.Worthington @bp.com Printed Na : Joe a ,cE(;,a t Title: Drilling Technologist Signatur • ' ill„ ` Phone: 564-4091 Date:1'� 15113 Form 10-404 ised 10/2012 Submit Original Only 404 41, 1 17r 1/13) 113 RBDMS JUL 2 3 2”` fitPS-37 CHOPS Com p Dion Drive Head' Grenco D2100, 40 Hp - Orig. DF Elev. =71.88' (D-14) 8" Motor sheave, 14" Drive Sheave Orig. GL Elev. =38.10' (D-14) Production Flow Tee: FMC 11"5M DF to Csg Spool = 32.61' (D-14) x 4 1/16" 3M top and outlet flanges Wellhead' 11"x 4 1/2" FMC Gen V Tubing Hanger, TC-II t&b thread, 4"CIW'H' BPV profile 20"welded/insulated, 106' 91.1 ppf, H-40 7" ES Cementer 3372` 9-5/8"40#/ft., L-80 BTC 3857' Heat Trace Cable 3434' KOP 6500' 500' Max Hole Angle= 34 deg.f12700' ***No McOH or Diesel in well to 3000' Hole angle through perfs. =20 deg. due to risk of swelling elastomer DLS = 5.5 deg+100' @ 1386' in pump stator*** Tbg x rod annular capacity: 0.0077 bpf < SLB 0.433" Encapsulated TEC wire IA capacity: 0.0264 bpf NOTE: EVERYTHING from Shear 4 1/2" 12.6#/ft., L-80, TC-II & Hyd 563 SC Tbg Sub up was pulled out of well 6/20/13 (drift ID= 3.833", cap. =0.0152 bpf) , 700' 1-1/4" OD Giraffe String 3 1/2' 9.3 ppf, L.80, EUE 8rd Tubing ' w/30K Shear Sub(Top) (drift ID = 2.867',cap. =0.0087 bpf) Volant MLT Torque rings in tubing couplings 'I Tbg Drain Sub, 3300 psi 3999' 7"26#/ft., L.80. BTC, production Csg (drift ID =6.151 ,cap. =0.0383 bpf) X-over Pup 4 1/2"x 3 1/2" 4144' 3-1/2" KBMG LTS Chem. 4160` inj Mandrel C� SLB TEC Gauge carrier 4200` 3.5"9.3# L-80 EUE 8rd tbg with Torque rings Pail C apt l�ii.t r „. 4`pupls-L}t a1 i2" Ref Log SLB Natural GR Log 26-Jun-07 Boronized tbg 4219` Size SPF Interval (TVD) — WFD 220-5100 PCP 4255` 5" PF 5008 8 4260-4275' 3865`-3879' w/21' rotor(1 71 stator ID) 4277' 4.5" PJ 5 4260-4275' 3865'-3879' — Slotted Tag Bar 4505 7" Baffle Adapter(PBTD) 4380' 7"float collar 4442' "XXXXX Jet Charges @ 60 deg. phasing" , 7"float shoe 4794' DATE REV. BY COMMENTS MILNE POINT UNIT 6/29/07 Hulme Drill and csg set- D-14 WELL MPS-37 8/26/08 McLellan Nabors 3S completion API NO. 50-029-233550-00 6/21/10 REH Nabors 4ES- ESPCP RWO 6/20/13 B. Bixby Pull Co-Rod BP EXPLORATION (AK) • • MPS-37, Well History Date Summary 06/12/13 Pull Co-Rod and rotor. Secure well for LTSI.Arrive on location. Hold PJSM. Primary Barriers= Pack off and KWF, (no floe well). Secondary barriers=radigans and KWF. Drive head electrically disconnected. RU WFD crane to pull Grenco drive head. Closed and torque upper radigans per procedure. Closed and snug lower radigans per procedure. Pressure test to 300 psi (low). PASSED. Pressure test to 2000 psi (high). PASSED. Removed six bolt clamp. Loosened packing gland. Removed Grenco drive head. RD and move to MPS-43. CH2 rigged up(2)4 1/16"gate valves, pump-in sub and hardline. 06/18/13 Rig up to pull Co-rod and Rotor. Start bleeding down well. Stump tested BOP's.Test waived by AOGCC, CH2 bled IA. 06/19/13 T/I/0=60/60/0 Load Tbg&IA w/152 bbls 9.6#brine. FWHP's=660/450/0 Weatherford in control of well at LRS dep. 06/20/13 Pull Co-Rod. Secure well for LTSI. Primary barriers= KWF. Secondary barriers=BOPs.Arrive location and hold PJSM. Inspect and warm up equipment. Full body pressure test on BOPs, pump-in-sub and gate valve. Both low and high full body pressure test and charted. Passed. Initial WHP=110 psi/IA=130 psi.Attempt to bleed WHP for no-flow test. Bled well to 12 psi. Continue to bleed well without attaining 0 psi. Call town engineer. Decision made to load well with 9.6 brine. Load IA with 150 bbls 9.6 brine. Bled well to 0 psi and watch overnight. Return in Am.tbg and IA on slight vac. Neutral wt 17k#. Maintain open bleed to tanks(slight vac on tbg/IA). Begin pulling to lay down polish rod and jointed pipe. Up wt 30k#no over pulls. Lay down polish rod and jointed pipe. Spool up 3350'of corod.At surface. Shear coupling was sheared. Call town eng for further direction. Decision made to rig down and demob all equipment. Email pics of shear coupling to town eng. Secure well for LSTI (tree left with standard tree cap flange).WHP=O psi/IA=0 psi. Milne Pt wsl notified to freeze protect tbg/IA with Milne crude. NOTE: 700'GIRAFFE STRING AND 20' ROTOR LEFT IN WELL.WEATHERFORD 1-1/8"JAW STYLE FS 30K SHEARED COUPLING LOOKING UP. MAX OD 2.375"ESTIMATED TOP OF FISH 3552'md. Picture of recovered shear coupling placed in well file. Page 1 of 1 • w \ THE STATE Al it Gas 4 Of Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue rk P Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 MAC' 2 9 213 Fax: 907.276.7542 Aras Worthington SCANNED Well Intervention Engineer 0 5 a, BP Exploration (Alaska), Inc. a� P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Field, Ugnu Pool, MPS -37 Sundry Number: 313 -231 Dear Mr. Worthington: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P./Foerster Chair DATED this ?`f day of May, 2013. Encl. STATE OF ALASKA RECEIVED ALASIPOIL AND GAS CONSERVATION COMMQION j,, xf 0 9 2013 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 AOGCC 1. Type of Request: ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ® Other Pull PCP Rotor & Corod 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic 207 - 052 • 3. Address: ® Development. ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50.029 23355 - 00 - 00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? MPS -37 Will planned perforations require a Spacing Exception? ❑ Yes ® No 9. Property Designatior 10. Field / Pool(s): ADL 380109 & 380110 • Milne Point Unit / Ugnu 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): • 4814' • 4385' ' 4380' • 3978' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 20" 115' 115' 1490 470 Surface 3822' 9 -5/8" 35' - 3857' 35' - 3487' 5750 3090 Intermediate Production 4761' 7" 33' - 4794' 33' - 4366' 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): •4260' - 4275' 3865' - 3879' 4 - 1/2 ", 12.6 # x 3 - 1/2 ", 9.3# L - 80 4280' Packers and SSSV Type: None . Packers and SSSV I MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ' ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ❑ Stratigraphic ® Development/ ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation: May 20, 2013 ® Oil- ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ❑ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Aras Worthington, 564 -4102 Printed Name: � Aras Worthington Title: Well Interventions Engineer Email: Aras.Worthington ©bp.com Signature: L %`` :`�- ", Phone: 564 - 4102 Date: 47/20 Commission Use Only _ y � ' 7 Conditions of approval: Notify Commission so that a representative may witness �� 3-51 Sundry Number: ❑ Plug Integrity BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: 75 0 /2 ff5 f /- UU ' RBC MS MAY 2 8 20 Spacing Exception Required? ❑ Yes ["No Subsequent Form Required: /v l= `674. 7 , f APPROVED BY Approved By: G" ' -• 'r / 1 } c,---- COMMISSIONER THE COMMISSION Date: ` ° - `t l Form 10-403 Revised 10 f 2012 Submit In Duplicate A pproOd R To1 a i N lid for_ 12 months from the date of ap p roval L �/Z3/!3 AL � � 512z8�3 � 1/ • • bP .....,.. „... M ilile < s Heavy Oil Team Today Future Forward MPS -37 Corod Pull Scope of Work: Pull PCP rotor and corod. MASP: 1339 psi (1720 psi @ 3808' TVD, less 0.1 psi gas gradient) Well Type: Ugnu Heavy Oil Producer Estimated Start Date: May 20th, 2013 Production Engineer: Mike Warren Intervention Engineer: Aras Worthington Corod scope of Work 1. MIRU Weatherford Flushby Unit and Mobile Gripper Unit. 2. ND Drivehead, NU dry hole tree. /1.7,0 f- ( —t 55f, 3. Stump Test Corod BOPE including 1 1/8” Rod rams and annular preventer to 2000 psi. 4. NU Corod BOPE to dry hole tree and body test to 2000 psi. f° es5 5. Pull corod and PCP rotor. 6. ND BOP stack. 7. RD Weatherford Flushby Unit and Mobile Gripper Unit. _ . • , III • MPS-37 CHOPS Completion Drive Head: Grenco D2100, 40 lip Orig_ DF Elev. = 71.86 (D-14) 8" Motor sheave, 14' Drive Sheave Orig. GL Elev. = 38.10 (D-14) Production Flow Tee: FMC 11" 5M DF to Csg Spool = 32.61' (D-14) x 4 1/16" 3M lop and outle4flanges _ Wellhead 11" x 4 1/7 FMC Gen V - 40' Polish Rod 1-1/2' OD Tubing Hanger, TC-Il t&b thread, _ 4" CIW 'H' BPV profile ii ■ 20' weldedhnsulated, 106 I Dry Rods 1-1W x 1 118", AOT grade 97 91.1 ppf, H-40 I I 7" ES Cementer I 3372' I 9-5/8' 40it-fft., L-80 BTC 3857' A ■ Heat Trace Cable I 3434' I KOP re 500' Max Hole Angle • 34 deg. V 2700' "*No Me0H or Diesel in well tu 30D0' due to risk of swelling elastomer Hole angle through perfs. = 20 deg. DLS e 5.5 deg/100' et 13%' in pump stator*" Tbg x rod annular capacity. 0.0077 bpf • WFD 1.156" OD Cored IA capacity. 0.0264 bpf SLB 0.433' Encapsulated TEC wire 4 1/2" 12.6#/ft., L-80, TC-Il & Hyd 563 SC Tbg (drift ID = 3.833', cap. = 0.0152 bpf) — 700' 1-1/4" OD Giraffe String 3 1/2" 0,3 ppf, L-80, EUE 8rd Tubing (drift ID = 2,867", cap, = 0,0067 bpf) I I VOlent MLT Torque rings in tubing couplings 11111.111. Dian Su 33 3999' 7° 26///ft, L-80, BTC, production Csg (drift ID = 6 151', cap, = 0.0383 bp() I X-over Pup 4 1/2' x 3 1/2' I 4144' _ I 3-1/2" KBMG-ITS Chem" 4160' • inj Mandrel P SLB TEC Gauge carrier 4200' 3.5" 9.3# L-80 EUE 8rd tbg with Torque rings .: , i 4' pup &1 jt 3-1/2' Ref. Log 5L13 Natural OR Log 26-Jun-07 "- "'` . Boronized flog 219 Size SPF Interval (TVD) r WFD 220-5100 PCP 4255' 5" PF 5008 8 4260-4275' 3865'-3879' I ' i L w/ 21' rotor (1.7r stator 113) 4277' 4.5" PJ 5 4260-4275' 3866-3879' Slotted Tag Bar - 4505 ir 7" Baffle Adapter (PBTD) I 4380' I r float collar I 4447 I "XXXXX Jet Charges #2) 60 deg. phasing" 7" float shoe 1 4794• DATE REV. BY COMMENTS MILNE POINT UNIT 6/29/07 Hulme Drill and csg set - D-14 WELL MPS-37 8/26/08 McLellan Nabors 38 completion API NO. 50-029-233550-00 6/21/10 REH Nabors 4ES - ESPCP RWO BP EXPLORATION (AK) • Page 1 of 2 Regg, James B (DOA) • From: Regg, James B (DOA) , Q. l `i Sent: Friday, April 15, 2011 5:15 PM �� To: 'Worthington, Aras J' Cc: DOA AOGCC Prudhoe Bay; Schwartz, Guy L (DOA) o Subject: RE: MPU CHOPS Wells SSV Variance The Well Safety Valve System (SVS) regulations - 20 AAC 25. 265 - effective December 3, 2010, provide for granting either a variance or waiver of the stated requirements; a variance if what is proposed provides at least an equally effective means of compliance; a waiver if what is proposed does not promote waste, is based on sound engineering /geoscience principles, will not jeopardize ultimate recovery, and does not increase risk to health, safety, environment. 20 AAC 25.265(c)(1) requires the surface safety valve (SSV) to be installed in the vertical run of the well's tree. As explained, this would be impossible to comply given the rod - driven downhole pumps used in the Cold Heavy Oil Production with Sand (CHOPS) project completions. BPXA's request for a temporary variance is approved. 20 AAC 25.265(c)(4) requires installation of a check valve in the well's flowline upstream of the production manifold. Your explanation indicates these check valves have not been installed, thus your request is not for a variance (equivalence) but a waiver [20 AAC 25.265(o)(2)]. BPXA's request for a temporary waiver is approved, but there needs to be additional discussion about the levels of protection in lieu of the check valves. These temporary approvals apply to Milne Point Unit wells S -37 (PTD 2070520), S -39 (PTD 2081830), S- 41 (PTD 2081590), and S -43 (PTD 2081760). Sufficient information has been provided to allow BPXA to begin operating these wells this weekend as requested in our phone conversation. Broader coverage (other wells) will be addressed in the Commission's response to BPXA's formal request as necessary. BPXA's formal request (letter application) covering the variance and waiver must be provided no later than Tuesday, April 19, 2011 (do not need to submit request by sundry application). Appropriate schematics as necessary and justification must be provided that can serve as the basis for the Commission's approval of permanent variance /waiver. Jim Regg AdIANED APR 0 201't AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Worthington, Aras 3 [mailto:Aras.Worthington @bp.com] Sent: Friday, April 15, 2011 4:26 PM To: Regg, James B (DOA) Subject: Mr. Regg, BPXA requests a temporary e variance to 20 AAC 25.265C for rod - driven pump wells at Milne Point: MPS -37, 39, 41, and 43 to allow the surface safety valve (SSV) to be located horizontally on the tree. Wells 37, 41, and 43 were completed prior to the regulation change that became effective December 3, 2010. A SSV in a vertical line with the tree (25.265C.1) is neither practical nor effective due to the need to accommodate the drive rod. 4/15/2011 Page 2 of 2 • Also, a variance is requested on 25.265C.4 which states that a check valve must be installed in the well's flow line upstream of the production manifold. Although check - valves are present on the annulus gas, and on the production lines prior to entering the atmospheric production tanks, they were not installed upstream of the production manifold due to the high fluid viscosities and initial sand -cuts that could plug the check - valves. BPXA will follow through with a formal request for variance for these wells complete with schematics and all necessary detail. Aras Worthington Wells Intervention Engineer BP Alaska Inc. (907) 564 -4102 4/15/2011 Schlum6erger Alaska Data & Consulting Services 2525 Gambell Street, Suke 400 Anchorage, AK 99503.2838 ATTN: Beth Weli Job 8 N0.5580 Company: State of Alaska Alaska Oil b Oas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD 1-27/P-20 01.01C 11-28A OS-25C AYKP-00085 BB6M-00016 AYKP-00061 BCUE-00021 RST - RST .~ RST MCNL ~ 06/06/10 06!09/10 05/31/10 06/02/10 1 1 1 1 i 1 1 1 Y-018 14-07 MPS-37 15-27A 15-27APBt BAUJ-00024 BBKA-00035 BCRC-00026 t0AKA0067 10AKA0067 MCNL RST RST ~ ~ OH MWDA.WD FOR OH MWDA.WD EDIT 05/25/10 06/06/10 06/21/10 05/14/10 05/08/10 1 1 t 2 2 1 t 1 1 1 PLEASE ACKNOWLEDGE REC EIPT Rv ctrsnnat r. eun ucr~~onnur_ n.~e nno.r ~...., :... BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Bivd. oe/os/1o Alaska Dala 8 Consulting Services 2525 Gambell Street, Sude 400 Anchorage, AK 99503.2938 • • ~a~C t'1~.~~:a a ~ 7~~~ ~~~~4~ ~ o~_ o sz ~ yips-a~ r_. I 27" ~ 1 ~ ._ i I i i I i i I s 6'9" I f I i i I i ^'12' A.G.L. .-- LJ COROD Safety 3-1/z a.5 sooo Lubricator 3-1/z otis sooo 3-1/z ot~s soon GKS Upper Annular 2-9/16 s000 R27 Bore 2.s6" GKS Lower Annular 2-9/16 6000 R27 Bore 2.56" Rod Ram 3-1/8" lOK X-Over 31/8" lOK X 41/16" Sk ~~ M ~Q ~nPs- ~7 ~ U7- b5Z 5TH ~~ JUL 2 Y 2010 ~~t~t Chi. SSlon ~~~~rage Assy #7473A Model GKS 4130 serial# 48618-3-ACD-2 Assy # 74736 Model GKS 4130 serial# 49618-3-ACD-1 Assy Model serial# Flanged Pump-In Sub/1502 Kill line Inlet; 24" OAL 41/16" sK X 41/16" sk Gate Valve 41/16" sK X 41/16" sk Radigan Spool/1502 Choke Line outlet ~~~. ,iU~~... ~ `~ r!i1~fia • m~ _ ~ ~ ~,: .p. :~~ ~~ ~ ~ ;~~ ,~ , emu„` .~. _ ~ MICROFILMED 6/3 0/2 010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE. C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS APR 2 1 201D e__ ia.e en w _ _ "`--_ /O~y1wIM~b01A/A 1. Operations Performed: ~n ^ Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended'W ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension Administrative Completion of Approval #309-340 2. Operator Name: 4. Well Class Before Work: .Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 207-052 3. Address: ^ Service ^ Stratigraphic .API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23355-00-00 7. Property Designation: ~ 8. Well Name and Number: ADL 380110 MPS-37 9. Field /Pool(s): Milne Point Unit / Ugnu Undefined Oil Pool 10. Present well condition summary Total depth: measured 4814 feet true vertical 4385 feet Plugs (measured) None Effective depth: measured 4380 feet Junk (measured) None true vertical 3g7g feet Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 20" 115' 115' 1490 470 Surface 3822' 9-5/8" 3857' 3487' 5750 3090 Intermediate Production 4761' 7" 4794' 4366' 7240 5410 Liner Perforation Depth: Measured Depth: 4260' - 4275' True Vertical Depth: 3865' - 3879' Tubing (size, grade, measured and true vertical depth): 3-1/2", 9.3# L-80 4286' 3889' Packers and SSSV (type, measured and true vertical depth): None 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Repair operations were unsuccessful. This 10-404 is being submitted to report on work conducted, and to close out Sundry approval #309-340, per request made by Mr. Guy Schwartz of the AOGCC. Anew 10-403, along with planned scope of work, was submitted on 04/08/10 to re-enter and repair this well. 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 13. Attachments: ^ Copies of Logs and Surveys run .Well Class after work: ^ Exploratory ®Development ^ Service Re ort of Well O erations ® Dail y p p ® Well Schematic Diagram Well Status after work: ®Oil ^ Gas ^ WDSPL ^ GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or WA if C.O. Exempt: Contact Aras Worthington, 564-4102 309-340 Printed Name Terrie Hubble Title Drilling Technologist ~'~' ~ Prepared By Name/Number: Signature Phone 564-4628 Date Terrie Hubble, 564-4628 Form 10-404 Revised 07/2009 ReDMS APR .~ 2 ~ `- c ~ Su~bm/it Original Only MPI~37 CHOPS Drive Head: Grenco D2100, 40 Hp 8" Motor sheave, 14" Drive Sheave Production Flow Tee: FMC 11" 5M x 3-1/8" 3M top and outlet flanges Wellhead: 11" x 3 1/2" FMC Gen V Tubing Hanger, TC-II t&b threads, 3" CIW `H' BPV profile 20" welded/insulated 106' 91.1 ppf, H-40 Completi~ Orig. DF Elev. = 71.88' (D-14) Orig. GL Elev. = 38.10' (D-14) DF to Csg Spool = 32.61' (D-14) 7" ES Cementer 9-5/8" 40#/ft., L-80 BTC 3857` KOP @ 500' Max Hole Angle= 34 deg.f12700' to 3000' Hole angle through perfs. = 20 deg. DLS = 5.5 deg+100' @ 1386' Tbg x rod annular capacity: 0.0077 bpf IA capcity: 0.0264 bpf 3 1!2"' 9.3 ppf, L-80, EUE 8rd Tubing (drift ID = 2.867", cap. = 0.0087 bpfj Volant M LT Torque rings in tubing couplings T' 26#Ift., L-80, BTC, production Csg (drift ID = 6.151", cap. = 0.0383 bpfj Formation sand: depth and amount unknown ~ 3.5" 9.3# L80 EUE 8rd tbg with Torque rings -.._ Perforation Summary Ref. Laa SLR Natural GR Log 26-Jun-07 $i~~: $PF In#~nr91 ;TVf7t 5" PF 5008 8 4260-4275' 3865`-3879' 4.5" PJ 5 4260-4275' 3865'-3879' 4505 "XXXXX Jet Charges @ 60 deg. phasing" DATE I REV. BY I COMMENTS 6/29/07 Hulme Drill and csg set - D-14 8/26/08 McLellan Nabors 3S completion Heat Trace Cable 3372` 3455` ***No McOH or Diesel in well due to risk of swelling elastomer in pump stator*** SLB 0.433" Encapsulated TEC wire 3953` Tbg Drain Sub, 4320 psi Corod Shear Tool, 30K # 3944` SLB TEC Gauge carrier 4224` MD 3831 ` TVD 1 jt 3-1/2" Boronized tbg 4233` WFD 82-8000 PCP 4265` w/ 21 `rotor d T S B 4284` ar lotte ag Centralizer 6.0" OD 4286` 7" Baffle Adapter (PBTD) 4380` 7" float collar 4442` 7" float shoe 4794` „. MILNE POINT UNIT WELL MPS-37 API NO. 50-029-233550-00 BP EXPLORATION OAK) • • BP EXPLORATION Page Operations Summary Report Legal Well Name: MPS-37 Common Well Name: MPS-37 Spud Date: 6/11/2007 Event Name: WORKOVER Start: 2/10/2010 End: 4/30/2010 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/26/2010 Rig Name: NABOBS 3S Rig Number: Date From - To Hours ~ Task Code NPT Phase Description of Operations 3/~" 010 00:00 - 00:00 24.00 WHSUR N SURE ** 200 BBLS OF 9.5 PPG BRINE BROUGHT OVER FROM 4ES JOB ON L-03 ** -OFFLOADED IN THE 3S PITS ,. `.~ ** MADE 24 HR NOTIFICATION CALL TO STATE FOR ~~, BOP TESTING @ 07:00 ~. -- LEFT A MESSAGE , GOT A R RN CALL FROM JOHN ~ ~ CRISP. 3/18/2010 00:00 - 06:00 6.00 W R P SURE NABOBS 3S IS ST KED ON MPS-37, DUE TO THE CHOPS WELL # 1 BEI SUSPENDED TWO NA S HANDS ON RIG -CO SIGNED MUD PUMP BY PUMPING THROUGH OKE RETURNING TO PITS -RIG tS IN PLACE OVER THE WELL WITH TESTED BOP'S -BOP'S ARE NIPPLED UP -BARRIERS IN PLACE ARE A TESTED 3-1/8" TWC - TED CLOSED MASTER VALVE '* 200 BBL F 9.5 PPG BRINE BROUGHT OVER FROM 4ES JOB ON L- -OFFLOADED IN T 3S PITS 06:00 - 11:00 5 MOB P PRE RESUMING CHOPS WE # 1 OPERATIONS -COMPLETED MPL-03 WELL, RI NG DOWN 4ES FOR MOVE TO TEXACO PAD -MOVING 4ES OFF MPL-03 -MOVING 4ES SUB AND PIPE SHED TO TEXA PAD TO BE WARMSTORED DURING CHOPS OPERATION . -RIG MOVE WAS DONE WITH LIMITED TRUCKS DUE __ SIMULTANEOUS RIG MOVE BY NABOBS 7ES 11:00 - 15:30 4.50 BOPSU P PRE TESTING 7-1/16" 5K, "GK" BOPE'S ON NABOBS 3S ~ -BOPE TESTED TO 200 PSI LOW , 2000 PSI HIGH -BLIND /SHEAR RAMS, 1" 5K DOUBLE GATE W/ 1" ROD ~\ RAM ~l g A~~e ~~~ ~ -7-1/16" 5K "GK" HYDIL ANNULAR (WITH 1"TEST JOINT) -CHOKE MANIFOLD VALVES ~M ' '3~~ -KILL & CHOKE MANUAL VALVES CHOKE HCR VALVES L JlJ t -KIL & -200 PSI BUILD UP FROM 2500 PSI = 15 SECONDS. -FULL BUILD UP TO 3000 PSI = 42 SECONDS. -4 BOTTLES 2000 PSI. -BOPE TEST WITNESSED BY JOHN CRISP, WSL T.P. 15:30 - 00:00 8.50 WHSUR P SURE CONTINUE TO LOAD AND MOVE 4ES TO TEXACO PAD. -RAISING THE DERRICK ON 4ES, SPOTTING PITS. -MOVED RIG CAMP TO S-37, CAMP ON S PAD AT 21:00 -RE SPOTTING THE 3S PIPE SHED -SETTING CAMP IN PLACE. 3/19/2010 00:00 - 01:00 1.00 RIGU P PRE REVIEWED MPS-37 PLAN FORWARD WITH TOOL PUSHER rnrnea: nnaizuw ~n4:iorrvi i ~ BP EXPLORATION Page t Operations Summary. Report Legal Well Name: MPS-37 Common Well Name: MPS-37 Spud Date: 6/11/2007 Event Name: WORKOVER Start: 2/10/2010 End: 4/30/2010 Gontractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/26/2010 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task Code NPT Phase. Description of Operations 3/19/2010 00:00 - 01:00 1.00 RIGU P PRE AND CREWS. -SWAPPED THE HYDRAULIC LINES FROM THE BOTTOM ANNULAR TO THE TOP - RIGGED UP BOP TEST EQUIPMENT 01:00 - 02:30 1.50 BOPSU P PRE TESTING BOPE'S -7-1/16" 5K, "GK" HYDIL ANNULAR (WITH 1"TEST JOINT) -TEST 200 PSI LOW AND 2000 PSI HIGH 02:30 - 04:30 2.00 RIGU P PRE RIG PREPERATION -ENVIRONMENTAL WALK AROUND. -CONNECT CHOKE HOUSE TO THE TIGER TANK. -DOUBLE CHECKING ALL THE LINES AND CONNECTIONS 04:30 - 06:00 1.50 PULL P DECOMP PU LUBRICATOR AND EXTENSIONS WITH OUT THE PIPE SHED IN PLACE -TEST LUBRICATOR TO 500 PSI -PULL TWC. LD LUBRICATOR 06:00 - 16:30 10.50 PULL P DECOMP RU CO-ROD SAFETY -RU MGU AND LINES TO WIPPER. -PU JDC, XO, 2-1/16" CSH FISHING STRING -RIH,TAG AND ENGAGE FISH @ 138' MD -PULL / LD 5 JTS AND FISHING TOOL -45K MAX PULL WT -25K ON RIG WT INDICATOR PULLING SUCKER ROD, 12 K OF THAT IS BLOCK WT. -LD SUCKER-ROD. 16:30 - 18:30 2.00 PULL P DECOMP LD FISHING STRING -CLEAN AND CLEAR FLOOR. 18:30 - 19:00 0.50 PULL P DECOMP PJSM WITH WEATHERFORD AND NABOBS CREWS. -DISCUSSED MOBILE GRIPPER UNIT, COROD INJECTOR LIFT PLAN. 19:00 - 21:00 2.00 PULL P DECOMP LIFTED MOBILE GIPPER UNIT TO THE RIG FLOOR. -SECURED MGU TO THE COROD SAFETY. -SECURED RIG FLOOR AND RELEASED WEATHERFORD CREW FOR MAXIMUM HOURS WORKED THEY WILL BE OUT AT 06:00 TO RESUME OPERATIONS. 21:00 - 00:00 3.00 PULL P DECOMP WEATHERFORD CREWS RELEASED FOR MAXIUMUM HOURS WORKED. -NABOBS CREWS MONITORING WELL, ONE GUY AT THE PITS FULL TIME AND ONE GUY ON THE FLOOR FULL TIME WATCHING FOR WELL ACTIVITY. 3/20/2010 00:00 - 06:00 6.00 PULL P DECOMP WEATHERFORD CREWS RELEASED FOR MAXIUMUM HOURS WORKED. -NABOBS CREWS MONITORING WELL, ONE GUY AT THE PITS FULL TIME AND ONE GUY ON THE FLOOR FULL TIME WATCHING FOR WELL ACTIVITY. -SLB CTD HAND WAS OUT TO LOOK AT PLACEMENT FOR THE CTU# 5. 06:00 - 09:30 3.50 PULL P DECOMP PJSM -WITH WEATHERFORD AND RIG CREW. - R/U WEATHERFORD GUIDE ARCH AND SPOOLING CAROUSEL. -TESTED LITTLE RED SERVICES LINES TO 1000 PSI. - R/U ELECTRICAL LINES AND CAMERA LINES TO WEATHERFORD INJECTOR. 09:30 - 12:00 ~ 2.50 PULL P DECOMP DOUBLE CHECK SYSTEMS AND LINES. Z Printetl: 4/19/'1010 9:74:16 PM • • BP EXPLORATION Page t~~ Operations Summary Report Legal Well Name: MPS-37 Common Well Name: MPS-37 Spud Date: 6/11/2007 Event Name: WORKOVER Start: 2/10/2010 End: 4/30/2010 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/26/2010 Rig Name: NABOBS 3S Rig Number: Date From - To. Hours Task.- Code 'NPT Phase' Description of Operations 3/20/2010 09:30 - 12:00 2.50 PULL P DECOMP -START PUMPING WITH LITTLE RED SERVICES THRU BOP STACK. 0.2 BPM AT 50 PSI WITH 90 DEG. F DIESEL. - REMOVE WEATHERFORD CLAMPS. START PICKING UP ON CO-ROD. WORK CO-ROD THRU GUIDE ARCH TO SPOOLER. - ATTACH CO-ROD TO SPOOLER. - PULL CO•ROD OUT OF HOLE WITH WEATHERFOD INJECTOR. CO-ROD IS CLEAN AND IN GOOD CONDITION. -PULLING THROUGH A CLOSED WIPER WEATHERFORD SHOWED 25K-38K PULL WT ON THE MOBILE GRIPPER UNIT. _ (ll IT (1F THE HC11 G \A/ITH (:(1_R(l~l AT 1 ~•nn PAA 12:00 - 12:30 0.50 PULL P DECOMP 12:30 - 15:30 3.00 PULL P DECOMP 15:30 - 20:30 5.00 PULL P DECOMP 20:30 - 00:00 3.50 PULL P DECOMP 3/21/2010 00:00 - 06:00 6.00 PULL P DECOMP 06:00 - 18:00 12.00 PULL P DECOMP 18:00 - 00:00 6.00 PULL N FLUD DECOMP 3/22/2010 00:00 - 03:00 3.00 PULL N FLUD DECOMP 03:00 - 04:30 1.50 PULL P DECOMP r0-ROD WAS PARTED AT SH AR SL1R ..SHEAR SUB PACKED FULL OF SAND. BREAKOUT SHEAR SUB. INSTALL ON THREADS OF CO-ROD. RIG DOWN WEATHERFORD GUIDE ARCH AND INJECTOR RIG DOWN 3" RISER. -R/U 7-1/16" FLANGED RISER -FROM TOP ANNULAR TO RIG FLOOR. PJSM WITH CTD -SLB CTD CREW LOOKING OVER LOCATION FOR RIG UP. -WAITING ON WELL SUPPORT CREW TOGETHER TOOLS AND HIGH PRESSURE LINES OUT OF PRUDHOE. -CREWS CHANGING OUT HEATER IN THE CELLAR OF 3S -WAITING ON WELL SUPPORT CREW TOGETHER TOOLS AND HIGH PRESSURE LINES OUT OF PRUDHOE. -CREWS CHANGING OUT HEATER IN THE CELLAR OF 3S -SECOND TIGER TANK SPOTTED IN PLACE;. ND RISER -NU BACK UP WITH A 3-1/8" DOUBLE VALVED PUMP IN SUB BELOW THE RIG FLOOR. -HARD LINE CREW RU HARD LINES TO CHOKE SKID AND TIGER TANKS. -SPOTTED AND RU CTU # 5 ,WITH 4-1/16" FULL PRESSURE CONTROL BOP. -SITE VISIT BY MPU FIELD MANAGER AND WELL OPS SUPERVISOR. WAITING ON CTU FLUIDS -AVALIBILITY OF TRUCKS VERY LIMITED DUE TO HEAVY FIELD OPERATIONS WAITING ON CTU FLUIDS -HELD A MEETING WITH NABOBS CREW AND CTU FOR UPCOMING COIL OPERATIONS -WAITING ON DIESEL AND GEO VISC FLUIDS. -AVALIBILITY OF TRUCKS VERY LIMITED DUE TO OTHER FIELD OPERATIONS. PJSM WITH SLB, LRS, CH2MHILL -ALL FLUIDS ARE ON LOCATION -SPOTTING LITTLE RED PUMP TRUCK AND CH2MHILL VAC UNITS. -PRESSURE TEST LITTLE RED LINES -STARTED PUMPING IN THE HOLE. Printed: 4/19/2010 3:14:16 PM • B'P EXPLORATION" Operations Summary Report Legal Well Name: MPS-37 Common Well Name: MPS-37 Event Name: WORKOVER Start: 2/10/2010 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/26/2010 Rig Name: NABOBS 3S Rig Number: Spud Date: 6/11 /2007 End: 4/30/2010 Date From - To Hours Task Code NPT Phase Description of Operations 13/22/2010 104:30 - 11:30 I 7.001 PULL I P 11:30 - 18:00 I 6.501 PULL I P 18:00 - 21:30 I 3.501 PULL I P 21:30 - 00:00 I 2.501 PULL I P 3/23/2010 00:00 - 07:00 7.001 PULL P 07:00 - 13:30 I 6.501 PULL I P 13:30 - 21:30 8.00 PULL P 21:30 - 22:30 1.00 PULL P 22:30 - 00:00 1.50 PULL P 3/24/2010 00:00 - 04:00 4.00 FISH P 04:00 - 10:00 I 6.001 FISH I P DECOMP RIH WITH 1-3/4" COIL ~ 30 FOOT PER MIN. -PUMPING IN WITH DIESEL -PUMPED 5 BBL OF KCL ~ 500' FOLLOWED BY 5 BBLS OF GEO VISC. -PUMPING 1.5 PER MIN Q 200 PSI. WILL SEE THE GEO VISC AT SURF WHEN WE HIT 1000' -TAGGED HARD FILL ~ 2500', NO PROBLEMS JETTING THRU IT. -TOP OF FISH -3936' CTMD. POOH. DECOMP PJSM. MAKING UP FISHING TOOLS. -1600 HRS ATTEMPT TO RIH -CAN NOT GO PAST TBG HANGER. DECOMP PJSM ON WITH SLB ON COROD LATCHING OPERATIONS -RIH W/ 1-3/4" COIL -TAG UP AT 3948' -MANY ATTEMPTS TO LATCH GIRAFFE STRING, PUMPS ON AND PUMPS OFF. -SET DOWN MAX OF 5,000 LBS -UNSUCCESFUL AT LATCHING UP TO THE GIRAFFE -POOH FROM 3948' DECOMP BREAK APART CTU LUBRICATOR ABOVE CTU BOP. -ND FISHING BHA. -WEATHERFOR FISHING HAND GOING BACK TO PRUDHOE TO PU DIFFERENT OVERSHOT AND UP / DOWN FISHING JARS. INTERN -WEATHERFOR FISHING HAND GOING BACK TO PRUDHOE TO PU DIFFERENT OVERSHOT AND UP / DOWN FISHING JARS. -WAITING ON WEATHERFORD INTERN PJSM. MAKING UP FISHING TOOLS. -RIH WITH CUTLIP GUIDE OVERSHOT W/ (TADITAILS) ON A MOTOR. -TAG AT 3948' CTMD -POH F/ 3948' CTMD. -RECOVERED NO SAND IN TOOL, -TADIT_AILES_C_OMFIRM TOOL WAS _O_VER FISH. INTERN PJSM. MAKING UP FISHING TOOLS. -RIH WITH CUTLIP GUIDE OVERSHOT -FISH AT 3948' CTMD 031630 HRS. -POH F/ 3948' CTMD AT 1830 HRS. NO FISH. MARKS ON GUIDE SHOE INTERN DICUSS OPTIONS WITH WELLS GROUP INTERN MU NOZZEL AND RIH TO CIRCULATE SWEEPS. DECOMP FINISH DISPLACEING McOH AT 3000' CTMD. -2% KCL IN CT AND IA AT 3800' CTMD, PUMP 6 BBLS GEOVIS. -TAG FISH AT 3957' CTMD, WITH 2K. -P/U AND SWAP TO 2% KCL -PUMP (3) 6 BBL GEOVIS SWEEPS OUT AT TOP OF FISH. -FREEZE PROTECT COIL AND POH AT 0330 HRS. -AT SURFACE. DECOMP CHANGE BHA Printed: 4/19/2010 3:14:16 PM • BP EXPLORATION Operations Summary Report Legal Well Name: MPS-37 Common Well Name: MPS-37 Event Name: WORKOVER Start: 2/10/2010 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/26/2010 Rig Name: NABOBS 3S Rig Number: Page tS~f=~ Spud Date: 6/11/2007 End: 4/30/2010 Date From - To Hours Task Code NPT Phase Description of Operations 3/24/2010 04:00 - 10:00 6.00 FISH P DECOMP -MU 10:00 - 12:30 ~ 2.501 FISH I P 12:30 - 18:00 I 5.501 FISH I P 18:00 - 00:00 I 6.001 FISH I P 3/25/2010 00:00 - 03:45 3.75 FISH P 03:45 - 06:00 2.25 FISH P 06:00 - 10:00 4.00 RIGD P 10:00 - 14:00 4.00 RIGD P 14:00 - 14:30 0.50 WHSUR P 14:30 - 15:00 0.50 BOPSU P 15:00 - 22:00 7.00 BOPSU P 22:00 - 22:30 0.50 BOPSU P 22:30 - 00:00 1.50 RIGD P 3/26/2010 00:00 - 04:00 4.00 RIGD P 04:00 - 06:00 2.00 RIGD P 06:00 - 22:00 16.00 RIGD P -FLUID PACK AND PRESSURE TEST COIL, 250 / 3500 PSI. -RIH, ENGAGE FISH AT 3957' CTMD -JAR UP / 26K WITH (50) HITS -PUMP OFF ON FISH. DECOMP POH F/ 3957' CTMD -UD TOOLS DECOMP CUT 150' 1-3/4" COIL. -M/U COIL CONNECTOR -PULL TEST TO 20K -PRESSURE TEST MHA TO 3500 PSI -M/U TO INJECTOR -WELL SUPPORT /.SERVICE MASTER VALVE DECOMP RIH FISHING ASSY CTC,DCV,SW_ IVEL,2 WT BARS JARS, DISCONNECT,ADJ & GS _ -SWAP OVER TO KCL. -TAG FISH @ 3930' CTMD. -UP WT 9500# DN WT 3850# -PU 24-28k 6 LICKS -CIRCUALTE 1.5 BPM~ 2000 PSI. -PUMP DN IA 1.5 BPM C~? 1500 PSI. -JAR 9 LICKS ~ 31-35K. -ON 16TH LICK PULL OFF UNABLE TO RELATCH. -PUMP MEOH DOWN CT -POH DECOMP MU 2-3/4" DOWN JET NOZZEL. RIH. SUCK KILL WEIGHT BRINE FROM RIG PITS. DECOMP CIRCULATE WELL TO 9.6 PPG BRINE. PU TO 2000' AND FREEZE PROTECT WELL WITH 50/50 MEOH. POST RIG DOWN COIL UNIT_ -FiU COIL BOPS ____ -LD COIL TOOLS -LD INJECTOR -RD UNIT POST CLEAN PITS -BLOW DOWN LINES POST SET AND TEST TWC -1000 PSI F/ 10 CHARTED MINUTES. POST ND CT BOP. ND WEATHERFORD_SPOOLS _ POST DISASSEMBLE BOP AND LD SAME. POST NU TREE CAP AND TEST TO 500 PSI. POST REMOVE 4ES EQUIPMENT FROM RIG IN PREPARATION FOR STACKING OUT RIG 3S. POST CONTINUE TO REMOVE 4ES EQUIPMENT FROM RIG IN PREPARATION FOR STACKING OUT RIG 3S. POST LOWER DERRICK. RELEASE RIG AT 06:00. POST SEPERATE AND SEND OUT EQUIPMENT FOR CHOP'S WELLTO DSM, WEATHERFORD, SCHLUMBERGER, AND BAKER OIL TOOLS -CLEAN OUT PITS, TANKS, AND CUTTINGS BOX IN PREPERATION FOR MOVING RIG ACROSS ASSET BOUNDRIES. 5 Printed: 4/19/2010 3:14:16 PM BP EXPLORATION Page .Operations` Summary Report Legal Well Name: MPS-37 Common Well Name: MPS-37 Spud Date: 6/11/2007 Event Name: WORKOVER Start: 2/10/2010 End: 4/30/2010 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/26/2010 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/26/2010 06:00 - 22:00 16.00 RIGD P POST -WORK WITH ENVIROMENTAL TO EMPTY SAA / RAA AREAS IN PREPERATION FOR MOVING ACROSS ASSET BOUNDRIES. -MOVE RIG 3S PIPE SHED OFF OF MPS-37 AND STAGE ON TEXACO PAD 22:00 - 00:00 2.00 RIGD P POST RIG 3-S CARRIER HAS AIR LINE /SHIFTING PROBLEMS ON TRANSMISSION. -PEAK TRUCK LOST REVERSE. 3/27/2010 00:00 - 06:00 6.00 RIGD P POST WORK ON CARRIER TRANSMISSION SHIFTING PROBLEM. -02:00 HRS PULL CARRIER OFF MPS-37 WELL -OVER HEATING AND SHIFTING PROBLEMS. -04:00 HRS SPOT CARRIER ON TEXACO -STAND-BY FOR MOVE TO NABOBS DEAD HORSE YARD -WHILE RIG 4-ES MOVES TO DS-9. Printed: 4/19/2010 3:14:16 PM • • ~~Q~[~ 0~ p~Q~~(Q /~..o..~LL~,~,~a Dan Kara Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 ..- d Re: Milne Point Field, Ugnu Undefined Oil Pool, MPS-37 Sundry Number: 310-119 Dear Mr. Kara: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~~day of April, 2010. Encl. ~ ~ STATE OF ALASKA ~/ + ` ~~ ~ (~I~~LAS LAND GAS CONSERVATION COMMI~N ~~~~~""' - ~ ~~~ APPLICATION FOR SUNDRY APPROVAL .~ ~ 20 AAC 2s_2so APR 0 ~ 2010 .~ 1. Type of Request: ~' ~ODS ~~j ~ ~ rF~~ ^ Abandon ^ Plug for Redrill ^ Perforate New Pool ®Repair Well ^ Chang ove ^ Suspend ^ Plug Perforations ^ Perforate ®Pull Tubing ^ Time Extension ^ Operations Shutdown ^ Re-Enter Suspended Well ^ Stimulate ^ ARer Casing ®Other See Attached: Rod String Replacement 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration, (Alaska) Inc. ®Development ^ Exploratory 207-052 3. Address: ^ Service ^ Stratigraphic 6. API Number. P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23355-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: MPS-37 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. Field /Pool(s): ADL 380110 Milne Point Unit / Ugnu Undefined Oil Pool .. 11 • - ` PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 4814 4385 4380 3978 None None Casin Len Size MD TVD Burst Colla Structural Conductor 1 4 Surface - / " 7' 4 7' S7 0 Intermediate Production 7 4 1 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4260' - 4275' 3865' - 3879' 3-1l2", 9.3# L-80 4286' Packers and SSSV Type: None Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ®BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: May 10, 2010 ®Oil ^ Gas ^ WDSPL ^ GSTOR ^ Abandoned 16. Verbal Approval: Date: ^ WINJ ^ GINJ ^ WAG ^ Plugged ^ SPLUG Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aras Worthin ton 564-4102 Printed Name Dan Kara Title Engineering Team Leader Prepared By Name/Number Signature Phone 564-5667 Date O Terrie Hubble, 564-4628 Commission Use Onl Conditions of approval: N tity Commission so that a representative may witness ~1 O ~ t (~ Sund Number: 1 , " , ~ ry ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance ~ z~oa Pf~ ~3v~ ~ S ~ --- Other: '~ 2t'SOa ~SL f-I h ~'~.. ~.ti. ~4-r ~~s Subsequent Form Required: 1 (' • ~ { ~ APPROVED BY ~ ZQ' ~ ~ ~ Approved By: COMMISSIONER THE COMMISSION Date Form 10-403 Submit In Duplicate f~~APR 2 0 2010 ~ ~ I G ~ ~ A y•lg-,a rf...~ ~.~~;vv • • ~ • 1, ~, Heavy Oil Team Today Fulvre Forward MPS-37 Rod String Replacement Scope of Work: Capital completion -Pull 1"Continuous Sucker rod string, clean out 3-1/2" tubing, run tubing caliper log, deploy new 1" Continuous Sucker Rod string. MASP: 1324 psi Well Type: Ugnu Heavy Oil Producer Estimated Start Date: February 10th, 2010 Production Engineer: Jim Young Intervention Engineer: Aras Worthington Pre-iob prep work 1. Perform No-Flow-Test on tubing. 2. Bullhead Kill weight brine into IA, 9.6ppg. 3. Set TWC. Scope of Work 1. MIRU Nabors 3S and Mobile Gripper Unit (MGU) for pulling Corod. NU BOPE for Sucker rod operation and test to 2000 psi. See attached BOP schematic. 2. RIH with fishing tools on the end of 120' of 2 1/16" DP. 3. Pull sucker rod string to surface. Lay down jointed sucker rods. 4. Pull 1"Continuous sucker rod string (open hole deployment). Note the tubing is plugged with sand, so it is not possible to circulate kill weight fluid into the well until the rod has been removed, The fluid in the tubing is a mixture of 12 deg API oil, water and sand, with diesel from the top of the rod string at 121' and to surface. 5. RD MGU. _~, 30~- 3y c~ Note: The above steps were completed on 3/27/2010, however the corod Shear Coupling 3960' MD was sheared. The main corod string was retrieved leaving the 300' "giraffe string" of corod in the well and a CTU attempt to fish the giraffe string on-rig was unsuccessful. 3S was rigged down and the plan forward is detailed as follows: 3~p_ ~ ~ Pre-iob area work 1. Pull TWC and Run Tubing Caliper on Slickline. 2. Punch holes in tubing above shear coupling with E-line.` 3. Circulate wellbore to diesel. 4. Perform No-Flow-Test on tubing witnessed by AOGCC Inspector. 5. Circulate well to Kill Weight Brine, Run TWC. • Rig work • 1. RU N4ES. 2. Pull TWC and Circulate Kill Weight Brine, Run TWC. 3. ND rod radigan spool. NU BOPs to Tubing Spool including 3'/s" pipe rams, blinds, and annular preventer. Test ROPE to 2000 psi. 4. Pull 3'/" Tubing, cutting and laying down 300' giraffe string. 5. CO to 20' below perfs. 6. Re-run 3'/z" tbg completion. Note: If 4'/2" wellhead equipment {rod radigan spool) is available, the rig may run a 4 %2" completion. BOP pipe rams will be swapped over to 4 %" if this is the case. 7. RD N4E5. 8. RU Weatherford Corod Mast Unit and BOPs including 1° pipe rams and (2) annular preventers. Note: if 4 "/" tbg completion is run, then 1 1/8" Corod will be run and thus 1 1/8" pipe rams will be installed instead of 1". Test BOPE to 2000 psi. 9. Run 1" (1 1/8" if 4 '/" tbg is the completion) Corod with Drive Rods for space-out to surface. 10. Close Wellhead polished rod rams and pressure test between the rams to 2000 psi. 11. ND BOP stack and gate valve. 12. Install electric rotating drive head. Pressure test Drive Head seals to 1500 psi. 13. RD Weatherford Mast Unit. • Rig work 1. RU N4ES. 2. Pull TWC and Circulate Kill Weight Brine, Run TWC. 3. NU BOPs including 3'/z" pipe rams, blinds, and annular preventer. Test BOPE to 2000 psi. 4. Pull 3 ~/z" Tubing, cutting and laying down 300' giraffe string. 5. CO to 20' below perfs. 6. Re-run 3'h" tbg completion. 7. RD N4ES. 8. RU Weatherford Corod Mast Unit and BOPs including 1"pipe rams and (2) annular preventers. Test BOPE to 2000 psi. 9. Run 1" Corod with 1.25" Sucker rod space out joints and 1.25" polished rod. 10. Close Wellhead polished rod rams and pressure test between the rams to 2000 psi. 11. ND BOP stack and gate valve. 12. Install electric rotating drive head. Pressure test Drive Head seals to 1500 psi. 13. RD Weatherford Mast Unit. ,,~S-37 Drive Head: Grenco D2100, 40 Hp 8" Motor sheave, 14" Drive Sheave Production Flow Tee: FMC 11" 5M x 3-1/8" 3M top and outlet flanges Wellhead: 11" x 3 1/2" FMC Gen V Tubing Hanger, TC-II t&b threads, 3" CIW `H' BPV profile ~ 20" welded/insulated 106` 91.1 ppf, H-40 Current StatuSi 7" ES Cementer 9-5/8" 40#/ft., L-80 BTC 3857` KOP @ 500' Max Hole Angle = 34 deg. f/ 2700' to 3000' Hole angle through perts. = 20 deg. DLS = 5.5 deg/100' @ 1386' Tbg x rod annular capacity: 0.0077 bpf IA capcity: 0.0264 bpf 3 1/2" 9.3 ppf, L-80, EUE 8rd Tubing (drift ID = 2.867°, cap. = 0.0087 bpf) Volant MLT Torque rings in tubing couplings 7° 26#/ft., L-80, BTC, production Csg (drift ID = 6.151", cap. = 0.0383 bpf) Sand Plug 3.5" 9.3# L80 EUE 8rd tbg with Torque rings ~ Perforation Summary Ref. Log SLB Natural GR Log 26-Jun-07 Size SPF Interval (TVD) 5" PF 5008 8 4260-4275` 3865'-3879' .5" PJ 5 4260-4275` 3865'-3879' 4505 "XXXXX Jet Charges @ 60 deg. phasing" DATE I REV. BY 6/29/07 Hulme 8/26/08 McLellan 7/23/09 McLellan COMMENTS Drill and csg set - D-14 Nabors 3S completion Proposed post rod swap Heat Trace Cable 3372` 3455` "**No McOH or Diesel in well due to risk of swelling elastomer in pump stator*"* SLB 0.433" Encapsulated TEC wire Sheared Corod shear- / coupling 3953` Tbg Drain Sub, 4320 psi Corod Shear Tool, 30K # 3944` SLB TEC Gauge carrier 4224` MD 3831 `TVD -1 jt 3-1/2" Boronized tbg 4233` WFD 82-8000 PCP 4265` w/ 21' rotor B Sl tt d T 4284` ar o e ag Centralizer 6.0" OD 4286` 7" Baffle Adapter (PBTD) 4380` 7" float collar 4442` 7"float shoe 4794` MILNE POINT UNIT WELL MPS-37 API NO. 50-029-233550-00 BP EXPLORATION (AK) MPS-37 RWO Schwartz, Guy L (DOA) ~~P From: Worthington, Aras J [Aras.Worthington@bp.com] Sent: Monday, April 19, 2010 2:43 PM To: Schwartz, Guy L (DOA) Subject: MPS-37 RWO Attachments: MPS-37 Scope of Work ver5.doc Guy, Here is the scope of work document with the discussed changes. Page 1 of 1 ~v 7-p S Z Also please note that we would like to keep the option open to run a 4 1/2" tubing completion if we have the proper equipment availability (the 4 1/Z" rod radigan spool). As noted, if we go with 4 1/2" tubing the corod will be 1 1l$" nominal, rather than the 1"for the 3 1/2" completion. Thanks, Aras Worthington ADW HOT/CHOPS Intervention Engineer Bp Alaska Inc. (907) 564-4102 «MPS-37 Scope of Work ver5.doc» 4/19/2010 MMPS-37 Nabors 3S RWO BOP - r~sed • Page 1 of 2 Schwartz, Guy L (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, February 12, 2010 2:32 PM To: DOA AOGCC Prudhoe Bay Cc: Schwartz, Guy L (DOA) ~ ~-~~ - ~~,~..,- Subject: FW: MPS-37 Nabors 3S RWO BOP -revised Attachments: BOP Stack Design for Corod alone - N3S.xls All, In Guy's absence, I got a call regarding the workover BP has planned on the MPS-37 Ugnu well. They completed this well with a co-rod and wound up twisting the polish rod off when they last attempted to operate. They have obtained a sundry to workover the well. As originally presented they planned to connect their choke and kill lines to the BOP body and presumed that theirbq. kith were into the same "space" on the stack. It appears that there are two outlet but one is above their ms and the other is between the pipe and blind rams. What has been presented here is to allow BP to flan up a cross externally to the vertical run of the wellbore using the outlet between the rams. This does not allow any circulation/injection into the well when the pipe rams are closed. Apparently BP's internal requirements are to have a pipe ram below their choke and kill connections. I asked about if they were pursuing an internal waiver to allow NU below the pipe ram and he said they were but were pursuing multiple paths. The actual procedure will be a combination of coil and Nabors 3S. When coil is rigged up they will have their complete BOP stack and choke/kill system above anything that 3S has on the hole. I wanted to get this out to get people's thoughts. I am not wild about what they are proposing. The fact that this well is low pressure may mitigate some of the discomfort. I told Aras that it was not likely to have an answer quick. I did not ask if they had another 7-1/16" double. I've not worked with outlets on a stack. I guess it makes sense to have the outlets like he says they have so you can pump in with the pipe rams closed or with the blind rams closed. It would seem that they should be considering being flanged up to both outlets. Thanks in advance. Tom From: Worthington, Aras J [mailto:Aras.Worthington@bp.com] Sent: Friday, February 12, 2010 1:59 PM ~~~ ~r~~ ~ ~; (;'ir To: Maunder, Thomas E (DOA) Cc: Kara, Danny T; Cismoski, Doug A Subject: MPS-37 Nabors 3S RWO BOP -revised Tom, This diagram should make more sense than what I tried to describe on the phone. The 2 1/16" Targetted Flow-Tee will be flanged to the dual rams, between the pipe and the blind rams, Everything to the rig choke will be flanged connections, but since the dual BOP ram-body has only one flanged port between the rams, the flow cross will be moved horizontally outside the BOP bodies by about 1'. The original BOP drawing we had sent showed the choke line coming from the opposite side of the ram body but there is only one flange connection between the rams, thus the proposed change. Aras Worthington CHOPS Intervention Engineer BP Alaska Inc. 2/~ 6/2010 r ~• ._ • BOPE for CoRod Pulling/Deploying Nabors 35 Rig-up Corod Safety 1.64' Note: Connections above fs annalar are threaded Riser Annular Preventor 3.0' Corod Wiper Top Corod safety, ideally 3' above rig floor, good working level. Corod Safety Note: BOP and Wellhead heights are approximate 7" Otis Quick Union To Shakers -> Top of floor to GL = 22' above GL Bottom of rig floor = 19' above GL Hydril "GK" Top of this Annular 14.25' above GL Hyan7 "GK" This annulaz to be used as a "rod wiper" only Annulaz Preventor 3.0' •.!7.1/16" SK • Choke line flanged to rig choke manifold, in turn hazdlined to micro-motion/choke trailer and to tiger tank ~ 7-1n6,5K Q ~jK Blind/Sheaz Ram Top of double gate 11.125' above GL 7-I/16" SK double gate .875' To Kill 1"rod Ram I ~ Flanged Connections on choke/kill 7-1/16", SK ~~,~ 2 1/16" SM Tazgetted flow Block 3-1/8" SK x 7-1/16" SK DSA ~1.0' Flanged to the port between blinds and pipes b ~~ 3-1/8 SK bp`''~ r~ 3-1/8", SK Gate valve 3-1/8" SK gate valve 1.563' (~ ~;ty~. Top 8.25' above GL Approximate physical measurement 3-1/8", SK X/O 3-118" 3K x 3-1/8" SK 0.6' 3-1/8, 3K 3-I/a^, 3K Radigan spool top 6.15' above GL Radigan spool 2.33' ~ <- Lil Red Diesel 1-1/4" Polished rod rams l l" SOOOt! u" sooou Top tubing spool 3.80' above GL To Choke Line -"'~' ~ ~0°~ o Kill I1"5000# I1" SOOOk RE: MPS-37 RWO Schwartz, Guy L (DOA) From: Worthington, Aras J [Aras.Worthington@bp.com] Sent: Wednesday, January 13, 2010 1:50 PM To: Schwartz, Guy L (DOA) Subject: RE: MPS-37 RWO Guy, ~~~ Page 1 of 2 ~a7-OJ L Sorry for the delayed response - I'm in Maui now taking a week of vacs here but headed back to Anchortown soon. We plan to run only the 1"corod rams at the start of the RWO since the length of 2 1/16" DP is minimal. Also, there will be two (2) annulars in the stack (one as a preventer, and one to use as a "rod wiper"). We plan to change the ram over to 1.75" when we RU CTU, then back to 1" when we get ready to re-run corod. Aras Worthington CHOPS Intervention Engineer BP Alaska Inc. 564-4102 From: Schwartz, Guy L (DOA) [mailto:guy.schwariz@alaska.gov] Sent: Friday, January 08, 2010 9:25 AM To: Worthington, Aras J Subject: RE: MPS-37 RWO Aras, Thanks....the operation is clearly stated . Only one question left that I can think of . What is the BOP pipe ram change out schedule. Are you starting the operation with 2 1/16" rams for the fishing string drill pipe? And then back to 1"for the CoRod? I realize there is only 120' of pipe needed and a good share of that will be the fishing BHA. You state changing out the rams to 1.75" for the CT FCO operations only. Guy Schwartz Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Worthington, Aras J [mailto:Aras.Worthington@bp.com] Sent: Thursday, January 07, 2010 4:28 PM To: Schwartz, Guy L (DOA) Subject: RE: MPS-37 RWO Guy, Here is the updated scope of work for Nabors 3S. 1/13/2010 RE: MPS-37 RWO ~ ~ Page 2 of 2 Aras «MPS-37 Scope of Work ver3.doc» From: Worthington, Aras ] Sent: Thursday, January 07, 2010 1:13 PM To: 'Schwartz, Guy L (DOA)' Subject: MPS-37 RWO Guy, As we briefly discussed, BP's plan forward is to perform the Corod workover on MPS-37 Feb 10th 2010. Other than the change from the work being performed by the Klondike to being done off of Nabors 3S, the following changes have been made to the program: 1) We will perform a "no-flow-test" (NFT) as part of pre-rig wellwork to evaluate the well's condition without Kill- Weight Fluid (KWF) in the tubing (the sand plug precludes us from displacing the tubing with KWF). We will also pump KWF into the IA so the IA will be dead upon rig arrival. 2) After pulling all of the corod components and a CTU cleanout of the fill in the tubing, we will displace the well to sea-water (less than KWF, EMW is 8.8 ppg) and perform another No-Flow-Test on-rig. We plan to request a State Witness for this test so it is documented by both BP and the AOGCC as such. 3) After the on-rig NFT we plan to displace the well back to KWF (we will use 9.6 ppg brine so it can double as freeze-protection in the permafrost interval) for the remainder of the RWO (corod/pump rotor installation). Thanks and looking forward to your reply and any other information requests, Aras Worthington CHOPS Intervention Engineer BP Alaska Inc. 564-4102 1/13/2010 by MPS-37 Rod String Replacement • M avy Oil Team ~dav fufure Forward Scope of Work: Capital completion -Pull 1" Continuous Sucker rod string, clean out 3-112" tubing, run tubing caliper log, deploy new 1" Continuous Sucker Rod string. ~'~I ~~~f o ~(~, ~ MASP: 1324 psi prase-~~ 1°~""~ a~~l~ ~. Well Type: Ugnu Heavy Oil Producer _ ~~„~ /3o P Estimated Start Date: February 10th, 2010 s,~,~,,~r Production Engineer: Jim Young ' ~`~~ ' "" ~ ~.~-~o Intervention Engineer: Aras Worthington Note: This Sundry Application is requesting approval to pull and run the rod string under AOGCC regulation 20 AAC 25.288 "Well Control Requirements for Other Service Operations". The well control equipment and procedures that will be applied to this operation are stated in the attached document "BPXA Sucker Rod/Continuous Rod Well Control Equipment and Procedures", dated 9/9/2009. The coiled tubing portion of this procedure will operate under normal regulations for coiled tubing. Pre-iob prep work 1. Perform No-Flow-Test on tubing. i~i:;.~~ .~~~~ ~` `~ ~~~~ 2. Bullhead Kill weight brine into IA, 9.6ppg. 3. Set TWC. Scope of Work 4. MIRU Nabors 3S and Mobile Gripper Unit (MGU) for pulling Corod. NU BOPE for Sucker rod operation and test to 2000 psi. See attached BOP schematic. Well Control provisions for Rod deployment will be discussed in the attached document entitled "BPXA Sucker Rod/Continuous Rod Well Control Equipment and Procedures", dated 9/9/2009. 5. RIH with fishing tools on the end of 120' of 2 1/16" DP. 6. Pull sucker rod string to surface. Lay down jointed sucker rods. 7. Pull 1" Continuous sucker rod string (open hole deployment). Note the tubing is plugged with sand, so it is not possible to circulate kill weight fluid into the well until the rod has been removed. The fluid in the tubing is a mixture of 12 deg API oil, water and sand, with diesel from the top of the rod string at 121' and to surface. 8. RD MGU. 9. RU CTU. Set TWC. Change out pipe rams to 1.75°. Pull TWC. 10. Clean out fill from tubing. Displace well with sea-water. 11. Run tubing caliper log. 12. RD CTU. 13. Perform No-Flow-Test on tubing. 14. Circulate kill weight fluid into tubing and IA. 15. Change out pipe rams to 1 ° for Corod. ao~-_o~a N ~~ 16. RU MGU. Run PCP rotor on 1" Corod with 1.25" Sucker rod space out joints and 1.25" polished rod. 17. Close Wellhead polished rod rams and pressure test between rams to 2000 psi. 18. ND BOP stack and gate valve. 19. Install electric rotating drive head. Pressure test Drive Head seals to 1500 psi. 20. Pull rotor out of the stator without pulling polished rod out of stufFing box. Freeze protect tubing and annulus. Land rotor back in stator. 21. RD MG 8~ and Nabors 3S. N ~ BPXA Sucker Rod/Continuous Rod Well Control Equipment and Procedures 9/9/2009 (a) This document applies to through-tubing operations that are performed with sucker rod or continuous sucker rod (Corod). (b) A full lubricator system or open hole deployment type system will be used. (c) The rated working pressure of the blowout prevention equipment (HOPE) and other well control equipment will exceed the maximum potential surface pressure to which it may be subjected. (d) Well control equipment will include (1) one manual gate valve flanged to the wellhead or tree (2) at least three preventers, including (A) one annular type preventer. (B) one equipped with pipe rams that fit the size of the rod being used, except that pipe rams need not be sized to pump equipment, polished rods, or when deploying Corod, jointed sucker rods used for space out; (C) one equipped with blind rams (3) a hydraulic actuating system with (A) sufficient accumulator capacity to supply 150 percent of the volume necessary to close all BOPs, except blind rams, while maintaining a minimum pressure of 200 psi above the required precharge pressure when all BOPS, except blind rams, are closed, and all power sources are shut off; and (B) an accumulator pump system; (4) locking devices on the ram-type preventers; (5) one complete set of operable remote HOPE controls on or near the operator's station and, if these controls are not in close proximity to a rig platform floor, a second annular type preventer closing control located on the rig platform floor; and (6) a kill line capable of being attached with flanged or hubbed connections to the BOP body, spool, tree, wellhead, or other well control equipment. M M (7) for continuous sucker rod operation, a hydraulic actuated safety break designed to prevent free fall of the rod string in the event of a loss of mechanical control by the rod gripper unit. (e) The BOPE assembly will be tested as follows: (1) at least once a week, and after each repair, change, or use for well control or other equivalent purpose, or when routine use of the equipment may have compromised its effectiveness, BOP equipment will be function pressure-tested, using anon-compressible fluid, to the maximum potential surface pressure to which they may be subjected or the required working pressure specified by the AOGCC. (2) after each installation of BOPE or other well control equipment, the equipment will be pressure-tested, before wellbore entry, to the maximum potential wellhead pressure to which it may be subjected (3) non-sealing equipment will be function-tested weekly, after a repair or change, and after an action that disconnects the hydraulic system lines from the BOPE, except that if the rod string is continuously in the well, function-testing will be performed as soon as possible after the rod string is pulled out of the well and the BHA clears the BOP; (4) after each well installation of the BOPE, the BOPE hydraulic connections to the rams must be visually verified before wellbore entry; (5) BOPS test results will be recorded as part of the daily record, and will be provided to the commission in an approved format, within five days after completing the test; (6) at least 24 hours notice of each BOPE function pressure test will be provided so that a representative of the commission can witness the test; (7) the operator will report to the commission within 24 hours any instance of BOPE use to prevent the flow of fluids from a well. (f) A copy of any approved Application for Sundry Approvals (form 10-403) will be posted in the operator's cab along with any geologic hazards and a copy of the operator's standing orders specifying well control procedures. If an additional or separate substructure is used, a second set of standing orders will be posted on the rig platform floor. RE: MPS-37 RWO ~ ~ Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, January 08, 2010 9:25 AM To: 'Worthington, Aras J' Subject: RE: MPS-37 RWO Aras, Thanks....the operation is clearly stated . Only one question left that I can think of . What is the BOP pipe ram change out schedule. Are you starting the operation with 2 1/16" rams for the fishing string drill pipe? And then back to 1"for the CoRod? I realize there is only 120' of pipe needed and a good share of that will be the fishing BHA. You state changing out the rams to 1.75" for the CT FCO operations only. Guy Schwartz Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Worthington, Aras J [mailto:Aras.Worthington@bp.com] Sent: Thursday, January 07, 2010 4:28 PM To: Schwartz, Guy L (DOA) Subject: RE: MPS-37 RWO Guy, Here is the updated scope of work for Nabors 3S. Aras «MPS-37 Scope of Work ver3.doc» From: Worthington, Aras J Sent: Thursday, January 07, 2010 1:13 PM To: 'Schwartz, Guy L (DOA)' Subject: MPS-37 RWO Guy, As we briefly discussed, BP's plan forward is to perform the Corod workover on MPS-37 Feb 10th 2010. Other than the change from the work being performed by the Klondike to being done off of Nabors 3S, the following changes have been made to the program: 1) We will perform a "no-flow-test" (NFT) as part of pre-rig wellwork to evaluate the well's condition without Kill- Weight Fluid (KWF) in the tubing (the sand plug precludes us from displacing the tubing with KWF). We will also pump KWF into the IA so the IA will be dead upon rig arrival. 2) After pulling all of the Corod components and a CTU cleanout of the fill in the tubing, we will displace the well to sea-water (less than KWF, EMW is 8.8 ppg) and perform another No-Flow-Test on-rig. We plan to request a 1/8/2010 RE: MPS-37 RWO ~ ~ Page 2 of 2 State Witness for this test so it is documented by both BP and the AOGCC as such. 3) After the on-rig NFT we plan to displace the well back to KWF (we will use 9.6 ppg brine so it can double as freeze-protection in the permafrost interval) for the remainder of the RWO (corod/pump rotor installation). Thanks and looking forward to your reply and any other information requests, Aras Worthington CHOPS Intervention Engineer BP Alaska Inc. 564-4102 1/8!2010 MPS-37 RWO ~ ~ Page 1 of 1 ,. Schwartz, Guy L (DOA) From: Worthington, Aras J [Aras.Worthington@bp.com] Sent: Thursday, January 07, 2010 1:13 PM To: Schwartz, Guy L (DOA) Subject: MPS-37 RWO ~ ~S Guy, As we briefly discussed, BP's plan forward is to perform the Corod workover on MPS-37 Feb 10th 2010. Other than the change from the work being performed by the Klondike to being done off of Nabors 3S, the following changes have been made to the program: 1) We will perform a "no-flow-test" (NFT) as part of pre-rig wellwork to evaluate the well's condition without Kill- Weight Fluid (KWF) in the tubing (the sand plug precludes us from displacing the tubing with KWF). We will also pump KWF into the IA so the IA will be dead upon rig arrival. 2) After pulling all of the Corod components and a CTU cleanout of the fil! in the tubing, we will displace the well to sea-water (less than KWF, EMW is 8.8 ppg) and perform another No-Flow-Test on-rig. We plan to request a State Witness for this test so it is documented by both BP and the AOGCC as such. 3) After the on-rig NFT we plan to displace the well back to KWF (we will use 9.6 ppg brine so it can double as freeze-protection in the permafrost interval) for the remainder of the RWO (Corod/pump rotor installation). Thanks and looking forward to your reply and any other information requests, Aras Worthington CHOPS Intervention Engineer BP Alaska Inc. 564-4102 1 /7/2010 • • Mr. Dan Kara Engineering Team Leader BP Exploration (Alaska), Inc. D 5~ P.O. Bpx 196612 ~~ '' Anchorage, AK 99519-6612 .-....---... Re: Milne Point, Ugnu Undefined Oil Pool, MPS-37 Sundry Number: 309-340 ~~~~v~~~ ~ c~ ~~ ~ ~ Zoa~ Dear Mr. Kara: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When pro~~iding notice for a representative of the Commission to witness any required test, contact the Comrnission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court un?ess rehearing has been requested. Sincerely, Daniel T. Sea.~nount, Jr. ~ Chair DATED this" day of October, 2009 Encl. ~ ~ ~ ~ ~~,.~~ ~ STATE OF ALASK/~~ ~ ~~0 ALAS~IL AND GAS CONSERVATION COMM~ N ` APPLICATION FOR SUNDRY APPROVAL ~~ zo aac 2s_2go 1. Type of Request: . ^ Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Re-Enter Suspended Wef! ^ Alter Casing •~ Repair Well ^ Plug Perforations ^ Stimulate ~ Other Specify: ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Time Extension See Attached: Rod String Repl~ement 2. Operator Name: 4. Current Well Class: 5. Permit To Driil Number BP Exploration (Alaska) Inc. •~ Development ^ Exploratory 207-052 ~ 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23355-00-00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: MPS-37 . Spacing Exception Required? ^ Yes ~ No 9. Property Designation: ~ 10. Field / Pool(s): ~ ~" ADL 380110 Milne Point Unit / Ugnu L~~ ~~t i ~i o ~~• PRESENT WELI CONDITION SUMMNRY ` z`iz~ Total Depth MD (ft): Total Depth ND (ft): Effective Depth MO (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 4814 • 4385 • 4380 3978 None None Casin Len h Size MD ND Burst Colla e Structural Conductor 11 ' 115' 14 47 Surface 822' 9-5! " 3 57' 87' S75 3090 Intermediate Production 47 1' 7" 47 4' 7240 10 Liner PerForation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4260' - 4275' 3865' - 3879' 3-1 /2", 9.3# L-80 4286' Packers and SSSV Type: None Packers and SSSV MD (ft) and ND (ft): 12. Attachments: 13. Well Class after proposed work: ~ Description Summary of Proposal ~ BOP Sketch • ^ Detailed Operations Program ^ Exploratory ~ Development ^ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: October 5, 2009 ~ Oil , ^ Gas ^ WDSPL ^ GSTOR ^ Abandoned 16. Verbal Approval: Date: ^ WINJ ^ GINJ ^ WAG ^ Plugged ^ SPLUG Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Brian McLellan 564-5516 Printed Name Dan Kara Title Engineering Team Leader -~ Prepared By Name/Number: Signature~~ J L_ _ Phone 564-5667 Date c~ 21 oq Sondra Stewman, 564-4750 Commission Use Onl Conditions of approval•~fy Commission so that a representative may witness ~~ ~~D Sundry Number: ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance ~ '~{~~ ~ ,Q nh~a.~ ~o Zd~ ~ s ~ ~~Sf ~" 1 • / ~ Other: Subsequent Form Required: / O. O L/ ! APPROVED BY / 6 ~ ~ ~ ~ Approved By: COMMISSIONER THE COMMISSION Date Form 10-403 Revi~ed 07/2000 ~ Submit In Duplicate - ~~ ~ a~~ ~ ~,. ZZ v~ ~~~~~~~~L... ,a.Z,o~~ ~/ ~~ . ~ MPS-37 Rod String Replacement Scope of Work: Capital completion - Pull 1" Continuous Sucker rod string, clean out 3-1/2" tubing, run tubing caliper log, deploy new 1" Continuous Sucker Rod string. . MASP: 1324 psi Well Type: Ugnu Heavy Oil Producer Estimated Start Date: October 5th, 2009 Production Engineer: Jim Young Intervention Engineer: Bryan McLellan Note: This Sundry Application is requesting approval to pull and run the rod string under AOGCC regulation 20 AAC 25.288 "Well Control Requirements for Other Service Operations". The well control equipment and procedures that will be applied to this operation are stated in the attached document "BPXA Sucker Rod/Continuous Rod Well Control Equipment and Procedures", dated 9/9/2009. The coiled tubing portion of this procedure will operate under normal regulations for coiled tubing. Pre-iob arep work 1. RU Coiled tubing. RIH to 121' md and latch onto parted sucker rod. Pull rod to surface. Hang the ~ rod string off in the Radigan Head in the wellhead, using a 1-1/4" deployment bar in the fishing BHA. ~~( Close the rod radigans on the 1-1/4" deployment bar and hydraulically release the rod string from the coil. 2. RD Coiled tubing. Scope of W rk 3. MIRU Ktondike #1 and Mobile Gripper Unit (MGU) for pulling Corod. NU BOPE for Sucker rod operation and test to 2000 psi. See attached BOP schematic. Well Control provisions for Rod deployment will be discussed in the attached document entitled "BPXA Sucker Rod/Continuous Rod Well Control Equipment and Procedures", dated 9/9/2009. 4. RIH with fishing tools on the end of jointed sucker rod (open hole type deployment). The rod string will be hung off in the wellhead, so only ~2 sucker rods should be required. 1' ~ 5. Pull sucker rod string to surface with a crane. Lay down jointed sucker rods. ~ 6. Pull 1" Continuous sucker rod string (open hole deployment). Note the tubing is plugged with sar~d, M~~ so it is not possible to circulate kill weight fluid into the well until the rod has been removed. The fluid in the tubing is a mixture of 12 deg API oil, water and sand, with diesel from the top of the rod string at ~121' md to surface. 7. RD MGU. ~ 8. RU CTU. Install coil BOP stack on top of the annular preventor from the Sucker rod BOP stack. 9. Clean out fill from tubing. G~(/~, 10. Run tubing caliper log. 11. Circulate kill weight fluid into tubing. RD CTU. / . ~ 12. RU MGU. Run PCP rotor on 1" Corod with 1.25" Sucker rod space out joints and 1.25" polished rod. 13. Close Wellhead polished rod rams and pressure test between the rams to 2000 psi. ~ 14. ND BOP stack and gate valve. ~,, 15. Install electric rotating drive head. Pressure test Drive Head seals to 1500 psi. ~' 16. Pull rotor out of the stator without pulling polished rod out of stuffing box. Freeze protect tubing and annulus. Land rotor back in stator. 17. RD MG & Klondike unit. 1 ` • • BPXA Sucker Rod/Continuous Rod Well Control Equipment and Procedures 9/9/2009 (a) This document applies to through-tubing operations that are performed with sucker rod or continuous sucker rod (Corod). (b) A full lubricator system or open hole deployment type system will be used. (c) The rated working pressure of the blowout prevention equipment (BOPE) and other well control equipment will exceed the maximum potential surface pressure to which it may be subjected. (d) Well control equipment will include (1) one manual gate valve flanged to the wellhead or tree (2) at least three preventers, including (A) one annular type preventer. (B) one equipped with pipe rams that fit the size of the rod being used, except that pipe rams need not be sized to pump equipment, polished rods, or when deploying Corod, jointed sucker rods used for space out; (C) one equipped with blind rams (3) a hydraulic actuating system with (A) sufficient accumulator capacity to supply 150 percent of the volume necessary to close all BOPs, except blind rams, while maintaining a minimum pressure of 200 psi above the required precharge pressure when all BOPs, except blind rams, are closed, and all power sources are shut off; and (B) an accumulator pump system; (4) locking devices on the ram-type preventers; (5) one complete set of operable remote BOPE controls on or near the operator's station and, if these controls are not in close proximity to a rig platform floor, a second annular type preventer closing control located on the rig platform floor; and (6) a kill line capable of being attached with flanged or hubbed connections to the BOP body, spool, tree, wellhead, or other well control equipment. , ~ ~ (7) for continuous sucker rod operation, a hydraulic actuated safety break designed to prevent free fall of the rod string in the event of a loss of inechanical control by the rod gripper unit. (e) The BOPE assembly will be tested as follows: (1) at least once a week, and after each repair, change, or use for well control or other equivalent purpose, or when routine use of the equipment may have compromised its effectiveness, BOP equipment will be function pressure-tested, using a non-compressible fluid, to the maximum potential surface pressure to which they may be subjected or the required working pressure specified by the AOGCC. (2) after each installation of BOPE or other well control equipment, the equipment will be pressure-tested, before wellbore entry, to the ma~cimum potential wellhead pressure to which it may be subjected (3) non-sealing equipment will be function-tested weekly, after a repair or change, and after an action that disconnects the hydraulic system lines from the BOPE, except that if the rod string is continuously in the well, function-testing will be performed as soon as possible after the rod string is pulled out of the well and the BHA clears the BOP; (4) after each well installation of the BOPE, the BOPE hydraulic connections to the rams must be visually verified before wellbore entry; (5) BOPE test results will be recorded as part of the daily record, and will be provided to the commission in an approved format, within five days after completing the test; (6) at least 24 hours notice of each BOPE function pressure test will be provided so that a representative of the commission can witness the test; (7) the operator will report to the commission within 24 hours any instance of BOPE use to prevent the flow of fluids from a well. (~ A copy of any approved Application far Sundry Approvals (form 10-403) will be posted in the operator's cab along with any geologic hazards and a copy of the operator's standing orders specifying well control procedures. If an additional or separate substructure is used, a second set of standing orders will be posted on the rig platform floor. ~ • MPS-37 CHO PS Sta t us 7-14-09 Drive Head~ Gienca ~2100, 40 Hp Orig. DF Elev. = 71.88' (D-14) 8" Matot shea+re, 14' Drive Sheave Orig. GL Elev. = 38.10' (D-14) Praductinn Flaw Tee: FMC 11" 5M DF to Csg Spool = 32.61 `(D-14) x 31/8" 3M ~p and outlet il~nqea }p(g~@g~;11" x 3 1f7 FMC Gen V Tudng Henger, TGtI t&b threeds, 3' CIW `H' B~PV profle ~ 2Q' weldedlnsulated,~ 106' 91.1 ppf, H-40 Rod parted -~2t' CTIv1D fSR pin boking up wilh 3 tull su~ker t~ds abave the Coro strinc~ a - 9-518" 4QItJfi, L-80 BTC 3857' KOP ~ 500' Max HdeAngle = 34 deq. U2700' ~0 3000' Hde angle throuph peris. = 20 deg. QLS = 5.5 de91100' ~ 1386' Tbg x rod annular capecity: 0.0077 bpf IArapc~y:0.0264 bpf 31/7` 9.3 ppf, L~O, EUE 8rd Tubing (dnft ID = 2.86T, cep. = O.U087 bP~ Vblant MLT Torque rings in tubing oouplings T' 26#1ft., L-80, BTC, production Csg (drift ID = 6.t51`, cap. = 0.0383 bpfj 1" OD round Carod 3.5 9.3# L80 EUE 8rd Ibg with Torque rings ~ Slze SPF Inlerval (TVU) B' PF 5008 4.5' PJ 45Q5 8 4280~275' 5 42~0-4275' 3885'-38 i 9 38r 5' 36 ;~ "XXXXX Jet Charges f~ ~0 deg. phasir-~' ~ DATE REV. BY COAAMENTS 6l29l0? Hulme Drill erM csg set- D-1d 81261~8 McLeMan Nabors 3S campletbn 7l15l09 McLellen Update al~r puNing parted rod 7° ES Cemener ~ 3372' ~ HealTraoe Cable 3455' Fluid in IAis dead al from Milne ~'o~ facility. Fl~ud in tubing is unknown mixture of Ugnu Heavy Oil and fresh water (assumed to be -20-309~o wat~rj Diesel from paned rod to surface. *"No MeOH or Diesel in weN due to risk of swellir~g elasttimer in pump atator"' SLB 0.433" Encapsulated TEC wire Sand bridge in tubing, thought to be sorne~vhere abot~e the SLB TEC ra3~i,~e. San:J uol~nne ~s I~wely to be 2~4 C~t~l~, Tbg Drain Sub, 4320 psi 3953' Carod Shesr Tool, 30K f~ 3944' SLB TEC Gauge ceRier 422,q ~ M D 3631'TVD p~ a'~9 4233' WFD 82-8000 P~P 4265' w/ 21' rdor SbttedTag Bar 4264` Centralizer 6.0' OD 4286' 7° Baifle Adapter (PBTD) 4380' 7" fbat callar 4447 7" (bat shoe 4794` ~~ M ~-37 Drive Head: Grenco D2100, 40 Hp 8" Motor sheave, 14" Drive Sheave Production Flow Tee: FMC 11" 5M x 3-1/8" 3M top and outlet flanges Wellhead: 11" x 3 1/2" FMC Gen V Tubing Hanger, TC-II t&b threads, 3" CIW `H' BPV profile ~ 20" welded/insulated~ 106` 91.1 ppf, H-40 9-5/8" 40#/ft., L-80 BTC 3857' Proposed Comp~ion Orig. DF Elev. = 71.88' (D-14) Orig. GL Elev. = 38.10' (D-14) DF to Csg Spool = 32.61` (D-14) Polished rod 1-1/4" OD x 40' long KOP (c~ 500' Max Hole Angle = 34 deg. f/ 2700' to 3000' Hole angle through perts. = 20 deg. DLS = 5.5 deg/100' ~ 1386' Tbg x rod annular capacity: 0.0077 bpf IA capcity: 0.0264 bpf 3 1l7 9.3 ppf, L-80, EUE 8rd Tubing (drift ID = 2.867", cap. = 0.0087 bpf) Volant MLT Torque rings in tubing couplings 7' 26#/ft., L-80, BTC, produdion Csg (drift ID = 6.151°, cap. = 0.0383 bpf) 1" OD round Corod 3.5" 9.3# L80 EUE 8rd tbg with Torque rings Size SPF Interval" (ND) 5" PF 5008 8 4260-4275' 3865'-3879' 4.5" PJ 5 4260-4275' 3865'-3879' 4505 "XXXXX Jet Charges @ 60 deg. phasing" Drive rods 1-1/4" OD x 168' long 7" ES Cementer Heat Trace Cable 3372` 3455` *"`*No MeOH or Diesel in well due to risk of swelling elastomer in pump stator"`** SLB 0.433" Encapsulated TEC wire 3953~ Tbg Drain Sub, 4320 psi Corod Shear Tool, 35K # 3944` SLB TEC Gauge carrier 4224' MD 3831 `TVD 't~t3=~"Ba7onized tbg 4233` WFD 82-8000 PCP 4265` w/ 21' rotor Sl d T B 4284` otte ag ar Centralizer 6.0" OD 4286` 7° Baffle Adapter (PBTD) 4380` 7" float collar 4442' 7" float shoe 4794` DATE REV. BY COMMENTS 6/29/07 Hulme Drill and csg set - D-14 8/26/08 McLellan Nabors 3S completion 7/23/09 McLellan Proposed post rod swap BP EXPLORATION (AK) ~ • MPS-37 BOPE for Sucker Rod Pulling/Deploying Klondike #1 Rig-up Corod Safety L64' Rod wiper ???? & Riser space-out sections Note: Connections above ~ annular are threaded Riser Annular Preventor 3.0' Blind ram To Choke ~ 7-U16" SK double ~ate 1.875' I" rod Ram 3-1/8" SK x 7-1/16" SK DSA -l.0' 3-U8" SK gate valve 1.563' X/O 3-l/8" 3K x 3-1/8" SK 0.6' Radigan spool 233' To Choke Line Top Corod safety, ideally 3' above rig Floor, good working level. Corod Safety Note: BOP and Wellhead heigh[s are approximate Top of tloor ro GL = 22' above GL Bottom of rig floor = l9' above GL Hydril U16" Top of Annular 14.25' above GL Top of double gate 11.125' above GL To Kill Flanged Connections on choke/kill Gate valve Top 8.25' above GL Approximate physical measurement Radigan spool [op 6.15' above GL l-l/4" Polished rod rams Top tubing spool 3.80' above GL To Kill ~ Prom: McLellan, Bryan J [mailto:Bryan.McLelian@bp.com] Sent: Wednesday, September 30, 2009 3:15 PM To: Maunder, Thomas E(DOA); Schwartz, Guy L(DOAj Cc: Stewman, Sondra D; Kara, Danny T Subject: RE: (PTD 207-052) Sundry Application Tc~m & ~uy, Pursuant to our phone conversation ioday... • Here is a basic well history, contingency discussion and the remaining AWGRS reporis far the coil operation where we picked up an the rod string and then placed it back on bottom. Note that it did not go aii the way back dawn. it stopped ~13' above the top of the pump, Presumably because of sand fa{ling in below it. # reaiize that this is a very different type of well than we are used ta dealing with in Alaska. If you require addi#ionai inf~rmatian, please dan't hesitate to ask. Thar~k you, Bryan McLellan 564-5~16 WELL HISTORY MPS-37 was driiled as an experimental Heavy Oil CHOPS well. It has 3.5" L-80 tubing and a 1" continuous sucker rod (Corod) comple#ion with a progressing cavity pump (PCP), This completion includes a co-rod shear tool pinned to shear at 30,000 Ibs overpull and a hydraulic siiding sleeve (drain sub) in the tubing pinned to open at 4320 psi differential. Well is currently SI with a broken sucker rod connection. The upper 133' of rod string has been removed from the well, leaving a stripped, 1" sucker rod pin looking up. From 10/19-10/21/08, Coiled tubing attempted to fish the rod and establish TxfA communication so that the well could be freeze protected. The rod string was successfully latched with a special hydraulic JDC sized to catch the 2" upset on the sucker rod pin. Pick up weight was 54K Ibs to pull the rator out of the pump stator and then fell off to 40K Ibs. Calculated free hanging rod weight should be 10K Ibs. They were unable to push the rotor back into the stator, leaving ~13' befinreen the bottom of the rotor and the top of the pump stator. The top of the parted sucker rod was left at 121' ctmd. An attempt was made to open the tubing drain sub by pressuring the tubing up to 5000 psi, but T x IA communication was never established. This woutd indicate tha# there is sand above the tubing drain at 3953' md. It is possible to bullhead down the IA into the perforations and the IA is full of dead crude from Milne Point (0.373 psi/ft gradient). The rotating drive head was removed from the wellhead and a 3-1/8" 5M dry hole tree is in place. ~ • The heat trace cable was disconnected at surface, but will need to be turned on prior to job start up. CONTINGENCY DISCUSSION: The Scope of work in the Sundry application mentions that prior to pulling the rod out of the well with the Klondike unit and Mobile Gripper, we plan to send a coil unit out to the well. The CTU will attempt to pull the rod to surface and hang it off in the wellhead radigans. This coil work will answer some questions about the condition of the well. It is possible that the rod is stuck on bottom. If that is the case, the scope of work for the Sundry will most likely change to involve a workover rig. A revision to the procedure in the Sundry would need to be made at that time. If there is still considerable overpull on the rod when it gets to surFace, altemative means of removing the rod may be necessary, i.e. a larger crane may be required. If this is the case, the Sundry wilt not need to be revised because we would only be changing the type of auxiliary equipment. MPS-37 21tOct/2008 CTU #9 w/2.375" OD CT. ******** Continued fro 10/20/0$ W SR* ******* Packer set pressure up 4500 psi try to shear drain sub in tubing. Increase tubing pressure to 5000 psi Unable to shear drain sub Highest BHP seen was 5942 psi w IAP 1795 psi. Release packer POOH RDMO ******* Job Complete ******* MPS-37 20/Oct/2008 T/U0= 1100/10/0. Assist CTU (RWO Prep). Pumped 1 bbl of diesel through ckoke skid and down TBG. bringing pressure to 2900 psi. CTU dumping pressure to tiger tank. T'hey did this three times. Each time we pumped it was at <.1 bpm. Pumped a 27 bbls of 1 SO* crude down IA through ckoke skid trying to keep IAP below 600. IAP increased from 10 psi to 600 psi. after 22 bbls pumped. Pumped 5 more bbls to cool coils down. CTU got the okay to increase IAP to 1550 psi. Pumped another 32 bbls of 180* crude down IA. IAP increased to 1000 psi. Pumped 6 bbls of diesel to flush lines. CTU lined up to pump down TBG. Pumped .6 bbls down TBG. CTU lined up to pump down IA. Pumped another 30 bbls of 180* crude down IA. IAP increased to 1100 psi. Pumped b bbls of diesel to flush lines. CTU lined to pump down TBG. Pumped 1 bbl. of diesel down TGB. *** WSR continues on 10/21/08*** MPS-37 20/Oct/2008 CTU #9 w/2.375" OD CT. * * * * * * * * Continued fro 10/19/08 WSR* *****~` * Latched onto Corod pulled SOk started to move at 140' pulled up to 120' puling 40k stopped hanging wt. 14k. RBIH tag at129' PiJH to 110' gaining wt as pulling. Try to pump down tbg pressures up and bleeds slowly. Continue to try an pump down well. Increase pressure on tubing to 3000 psi and did not see any injectivity. Pump 180* F crude down IA in 3 stages of M 25 bbls each. Continued to try to inject down tubing with no success. Consult with town engineer and decide to POOH for treating packer. MIJ and RIH with Weatherford treating packer. Set packer at 114' CTM pressure up dovcm coil to 4500 psi watch BHP gauges seeing pressure build on gauges. ****** Continued on 10l21/08 WSR ******* MPS-37 20/Oct/2008 ( Assist CTU ) Continued from 10-19-08 WSR. Pumped 2 bbls Diesel down tubing to try and circulate fluid back up IA. Tubing . • must be plugged off. FWHP~ 1Q00/0/0 MPS-37 19/Oct/2008 T/U0=60/10/0. (Assist CTU) Pump 208 bbls diesel heated to 140* down coil tbg to assist w/ flushing crude from tbg & latching onto corod. Continued on 10-20-08 WSR. MPS-37 19/Oct/2008 CTU #9 w/2.375" OD CT. MIRU. MU and RIH with Weatherford MHA and 2.50" JSN. Jet wash tubing with 140*F diesel to 157' ctmd. PUH and continue washing tubing. RIH with WOT 2.50" Hydraulic overshot latch onto corod at 154'. PUH w 38k get a little movement to 141' work pipe for 2 hours start increasing PUW. * * * * * * Continued on 10/20/08 WSR * * * * * * (PTD 207-052) Sundry Appli~on ~ Page 1 of 2 Maunder, Thomas E (DOA) From: McLellan, Bryan J [Bryan.McLeilan@bp.com] Sent: Tuesday, September 29, 2009 4:54 PM To: Maunder, Thomas E (DOA) Cc: Stewman, Sondra D Subject: (PTD 207-052) Sundry Application Tom, In response to our phone conversation today... I looked up the Sundry records from last year to see what had been submitted. We noticed that on Sundry # 308-323, dated 9/12/08, no follow up forms were requested, which probably explains why we hadn't sent in the job reports. I've attached a summary of the reports from the work we did to pull the upper section of rod from the well. Please forward this note to Guy, as I don't have his email address. Feel free to call me any time tomorrow to discuss in more detail. Thank you, Bryan 564-5516 AWGRS MPS-37 17/Oct/2008 ***WELL S/I ON ARRIVAL*** DRIFT W/LIB*** RAN 2 25" LIB_TO 141' SLM. GOT IMPRESSION OF CIRCLE AB„QUT 1" OD,. ~ _.~ ~_u WELL LEFT S/I ON DEP. TURNED OVER TO DSO. *** JOB COMPLETE*** AWGRS MPS-37 OS/Oct/2008 RU Weatherford mobile gripper unit and install 2-9/16" Co-rod BOP's. Planted a 1.92" OD Bowen overshot to the polish rod stub connected to 1" sucker rod for a test joint. Performed BOP test with Jeff Jones (AOGCC) present during the LPPT of the lower annular. Confirmed there was no trapped pressure in the tubing. Pulled 38' of olish rod an ' f 1"_ sucker rod from we1l~The last iece of_sucker rod ulled from the well had a box end lookin~ down ar~d ---ap, _._ ~. ~__._,,.,..~.. p _.,.._..~.~--.--~~..~. ,~.--.-- the threads were completely stripped l~e the pin end was parti~al !y backed out and pulled the rest of the way ee. C osed both va ves on t e -1/8" dry hole tree, nippled down co-rod BOP's and installed the flanged tree cap. RD Weatherford mobile gripper. ***JOB COMPLETE*** *** Fish in the hole is a pin end of a 1" sucker rod" AWGRS MPS-37 OS/Oct/2008 T/I/0=0/0/0 (Assist pulling co-rod) BOP test 2000 psi HPT w/sea water. FWHP= 0/0/0 AWGRS MPS-37 02/Oct/2008 PREP WH FOR SUCKER ROD REMOVAL. CUT OFF ROD CAP WITH PIPE CUTTER AND HACKSAW. RU WEATHERFORD MG AND REMOVE TOP DRIVE. CUT OFF 2' OF POLISH ROD FOR PROPER SPACING OF TEST ROD. INSTALL DUAL GATE VALVES AND WETHERFORD BOP STACK. AWGRS MPS-37 O1/Oct/2008 Attempt to remove rod cap on polish rod. LRS pressure test between the ratigans *** See LRS detaile pump report** RU weatherford moblie gripper, Pulled rod cap up about 4" above top drive. Secure polish rod with upper and lower rat+i~ans• 9/30/2009 (PTD 207-052) Sundry Appl~on ~ Page 2 of 2 Made several attempts to remove rod cap. AWGRS MPS-37 O1/Oct/2008 T/I/0=40/vac/0 PT Ratigans/Hard line to Flow Back Tank (Pre-Secure) - PT ratigans 300 pis low, 2000 psi high. PT hard line to flow back tank 2000 psi-good. Pumped total of 1 bb160/40 methanol. IA/OA & wing open. Weatherford & HOT operator on well upon LRS departure. Final WHP's=Ratigan closed/0/0 AWGRS MPS-37 29/Sep/2008 T/U0=55/Vac/Vac. Temp=SI. Bleed TP, monitor BUR (for CHOPS). T FL NS. IA FL NS. Bled TP from 55 psi to 0 psi in 60 secs (all gas). Monitor 1 hr. TP increased 16 psi during monitor. Final T/I/0=16/Vac/Vac. MV=O. 1 WV, 1 IA=C. 1 WV, 1 IA, OA=OTG. NOVP. AWGRS MPS-37 27/Sep/20Q8 T/I/0=41/Vac/Vac. Temp=SI. LNFT-IA PASSED (for CHOPS). IA FL NS. Bled TP from 41 psi to 0 psi in 60 secs (all gas). Found IA on a Vac. Monitored 30 mins, TP increased 14 psi, IAP remained the same for a passing test. Final T/U0=14/Vac/Vac. MV=O. 1 WV, 1 IA=C. 1 WV, 1 IA, OA=OTG. NOVP. AWGRS MPS-37 26/Sep/2008 T/I/0=72/86/0 (Freeze Protect IA with 9.8 ppg NaCL Brine) - Bullhead down IA w/45 bbls 9.8 ppg NaCI brine to freeze protect. IA/OA open to gauges. Tag well & notify operator. Final WHP's=75/430/0 AWGRS MPS-37 26/Sep/2008 T/I/0=76/140/Vac. Temp=SI. LNFT-IA INCONCLUSIVE (CHOPS). IA FL @ surf. Bled IAP from 140 psi to 6 psi in 2.5 hrs (all fluid) (5.4 bbls). Switched to bleed trailer~lAPincrea 'ed 24 psi during switch. Continued bleed from 30 psi to 3 psi in 4.5 hrs (7 hrs total) (1 bbl, 6.4 bbls total). Bled TP from 76 psi to 0 psi in 60 secs (all gas). Monitored 30 mins, IAP increased 3 psi. Final T/I/0=0/6/Vac. 1 WV, 1 IA=C. 1 WV, 1 IA=OTG. MV=O. OA=OTG. NOVP. A_WGRS MPS-37 22/Sep/2008 T/I/0= 99/74/0+. Temp= SI. NFT-T ***Inconclusive*** (AOGCC). TBG FL near surface. No AL. Integral flange installed on TBG & IA. Bled TBGP from 99 psi to 0 psi to bleed tank in <3 mins all gas. Conducted GNFT PASSED, <50 qfph. B1ed IAP from 74 psi to 3 psi in 5 hrs to bleed tank with 5.5 bbls of returns. ~ 1~pm returns. IA returns never stabilized. SI, moni~ore or mins. increase psi, increased 25 psi, OAP unchanged. FWHPs= 4/28/0+. SV= C 2 WV, MV= O 2 IA, OA= OTG. 9/30/2009 ' PTD# 207-052, MPS-37 Sundry~plication ~ Page 1 of 1 Maunder, Thomas E (DOA) From: McLellan, Bryan J [Bryan.McLellan@bp.com] Sent: Wednesday, September 23, 2009 5:34 PM To: Maunder, Thomas E (DOA) Subject: PTD# 207-052, MPS-37 Sundry Application Tom, We recently submitted the Sundry application for well MPS-37, which is the heavy oil well that we discussed at our meeting with Doug Cismoski, Harry Engel and myself. At the meeting, we discussed that the well control equipment and procedures for deploying sucker rods would be applied for under section 20 AAC 25.288, which I have stated in the Sundry application. I forgot to mention on the Sundry application that the document "BPXA Sucker Rod/Continuous Sucker Rod Well Control Equipment & Procedures, 9/9/2009", attached to the Sundry, was adapted from section 20 AAC 25.286 of the AOGCC regs. Please let me know if you would like to discuss any part of the Sundry application. Thank you, Bryan McLellan 9/29/2009 , , MPS-37 Heavy Oil meeting (PTD#207-052) Page 1 of 1 , ~ ~ Maunder, Thomas E (DOA) From: McLellan, Bryan J [Bryan.McLellan@bp.com] Sent: Tuesday, Ju1y 28, 2009 8:44 AM To: Maunder, Thomas E (DOA) Cc. Cismaski, ~oug A; Engel, Harry R; Kara, Danny T Subject; MPS-37 Heavy Oil meeting (PTD#207-052) Attachments: MPS-37 Sce~pe of Work.doc; MPS-37 status 9-15-08.bmp; BOP stack for Klondike 7-28-09.pdf Tom, As a follow up to our conversation last week, BP would like to meet with the AOGCC on Tuesday, 8/4, 10:00 am, to discuss our upcoming plans to replace the sucker rod string in well MPS-37. This well is a heavy oil producer in the Ugnu. It has an unconventional completion v~rith a rod-driven progressing cavity pump {PCP). The reason for the meeting is to discuss what measures BP intends to take with respect to weli control, since the regulations do not clearly define what is required when deploying rod strings. I've attached a draft of the scope of work. At the end of the document I've attached the planned well controt measures. I've also attached the current wellbore schematic and BOP stack diagram. «MPS-37 Scope of Work.doc» «MPS-37 status 9-15-08.bmp» «BOP stack for Klondike 7-28-09.pdf» Please let me know if you have any questions or require additional information prior to the meeting. Thank you, Bryan McLellan 564-5516 9/29/2009 • ~(9~ ~asi ~ens~n. ~Ivd. ~?~~horag~, ~~ 9950~ .~u1~ 22, 2~09 ~h~istine i~/iah~ken Alaska Oi4 &i C'ras Conservation ~ommissior~ 333 ~iV. ?th Ave., Ste. 100 Anchorage, Alaska 99501 Dear Christine • Please find the enclosed core descriptions for the following Milne Point Unit wells: LIVIANO-OlA 500292334301 ;1~A'~ ~r -~~~ ~ PESADO-O1 A 500292334501 ~=~~'~ ~ ~-~ :' ;=; MPS-37 500292335 0 ~'Q~-~~~'~-'J ~--~--~- _ If you have any questions, do not hesitate to contact me. Sincerely, Erik Hulm BP Alaska Heavy Oil Team Resource & Development Team Leader hulmej C bp.com W (907) 564-4095 M (907) 242-7349 ~~{iC+Ew ~ ~~~. ~..~,;~ ~.: ~ t ~ ~ ~6, ~ ~ , ; 4,. .. _ >>~~; ti. ~ .:,.. ~ ~ a~ J~~ DATA SUBMITTAL COMPLIANCE REPORT 6122/2009 Permit to Drill 2070520 Well Name/No. MILNE PT UNIT UGNU S-37 Operator BP EXPLORATION (ALASKI~ INC API No. 50-029-23355-00-00 MD 4814 ND 4385 Completion Date 6/29/2007 Completion Status SUSP Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATI~N Types Electric or Other Logs Run: MWD, GR, RES, IFR/CASANDRA, DEN/NEU w/ACAL, SONIC (BAT), (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digitai Dataset Log Log Run Intervai OH / ry e meairrmt rvumner Name aca~e mea~a rvo ~cart stop cr+ rceceivea commencs D D Asc Directional Survey 0 ~4814 Open 8/23/2007 ~ og Cement Evaluation 2 Col 1 2530 4352 Case 9/27/2007 SCBL, SCMT-CB, GR 8- Sep-2007 D C Pdf 15560 ~ee Notes 0 0 Open 10/23/2007 Haif Scale Photos of Core Sampies C Lis 15693` Gamma Ray 100 4653 Open 11/19/2007 LIS Veri, AIT, CNT, ECS, OBM Platform Express. w/PDS and TIF graphics og 15693 Sonic 2 Blu 3851 4803 Open 11/19/2007 Sonic Scanner Log, OBMI2, GPIT, MSIP, PPC 26-Jun-2007 I C:L~og 15693 See-Idntes t~ ~. ~~) Blu 3851 4813 Open 11/19/2007 MD Platform Express TCOM, AIT, GR, CNL, TLD, ECS, NGT 26-Jun- , ~ 2007 Log 15693 S~es- ~+. ~ ~'~ Blu 3851 4813 Open 11/19/2007 ND Platform Express TCOM, AIT, GR, CNL, TLD, ECS, NGT 26-Jun- 2007 GLog 15693 See Notes Blu 4272 4316 Open 11/19/2007 Chronological Sample Taker CST, GR 26-Jun- 2007 og 15693 Gamma Ray 25 B~u 3851 4803 Open 11/19/2007 ND Natrual GR, AIT, GR, CNL, TLD, ECS, NGT 26- ~ -- -- -- Jun-2007 ~ u DATA SUBMITTAL COMPLIANCE REPORT 6122/2009 Permit to Drill 2070520 Well Name/No. MILNE PT UNIT UGNU S-37 Operator BP EXPLORATION (ALASKI~ INC API No. 50-029-23355-00-00 NI 4a14 1 VU 4J6~ l.Ofll(JICUVII UdIC OiG.7icVV~ l..VnifJroUU~i ota~ua ovor ~w~ent.7~awa i-v~~ v~~. i~ og 15693 Gamma Ray 25 Blu 3851 4803 Open 11/19/2007 MD Natrual GR, AIT, GR, CNL, TLD, ECS, NGT 26- Jun-2007 cl~og 15693 See Notes 5 Col 3851 4803 Open 11/19/2007 MD Elemental Capture Spec, AIT, GR, CNL, TLD, ECS, NGT 26-Jun-2007 • og 15693 See Notes 5 Col 3851 4803 Open 11/19/2007 ND Elemental Capture Spec, AIT, GR, CNL, TLD, ECS, NGT 26-Jun-2007 ~D C Lis 15800 ~~duction/Resistivity 150 4814 Open 12/28/2007 LIS Veri, ROP, GR, RPS, RPM, FET, NPHI, FCNT, NCNT, RHOB, DRHO Rpt 15800 LIS Verification 150 4814 Open 12/28/2007 LIS Veri, ROP, GR, RPS, RPM, FET, NPHI, FCNT, NCNT, RHOB, DRHO D C 15801 ~See Notes 0 0 Open 12/28/2007 EMF, PDS and CGM file logs Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? ~N Chips Received? Y / N Analysis Y ! N Received? Sample Interval Set Start Stop Sen! Received Number Comments Daily History Received? ~'" Formation Tops ~ Comments: • ~ \ DATA SUBMITTAL COMPLIANCE REPORT 6/22/2009 Permit to Drill 2070520 Well Name/No. MILNE PT UNIT UGNU S-37 MD 4814 TVD 4385 ~ Completion Date 6/29/2007 Compliance Reviewed By: ~~ Operator BP EXPLORATION (ALASKIy INC API No. 50-029-23355-00-00 Completion Status SUSP Current Status 1-OI UIC N Date: ~ ~ ~ ~ MPS-37 Rod BOPE Test Page 1 of 1 ~ ~ Maunder, Thamas E (DOA) From: McLellan, Bryan J [Bryan.McLellan@bp.com] Sent: Wednesday, dctober 15, 2008 11:02 AM To: Regg, James B(DOA); DOA AOGCC prudhoe Bay; Fleckenstein, Robert J(DOA) Cc: Maunder, Thomas E(DQA); Rea, J~ffrey A(Qrbis) Subject: MPS-37 Rod BOPE Test Attachments: BOP Test MPS - 37 10-05-08.x1s Jim, !'ve attached the MPS-37 Rod BOPE test result form. This is in reference to Sundry # 308-323 and BOPE test done on 10/4/08. This operation was done non-rig, utilizing a pump truck and a cr~ne, so th~ R"rg # was left biank on the form. «BOP Test MPS - 37 10-05-08.xis» Thank you, Bryan Mc~eilan __ 564-5516 ~ ~,~~~!~~,: N~ ~` ~. ~.''' 2Q~S ~ ~~~. ~'~`'~~ ~ ~~ ~. 11/10/2009 STATE +t~F ALASKA '~11/14/07 OIL AND GAS ~C+~I~SERVATI~N C!~N~Ail1SSION 80PE Test Report sutnnitto: ,, Contractor. Ri~ No._ DATE: 10/5/2008 Rig Rep.: Rig Phone: Rig Fa~: Operator. BP Op. P~ear~e: 670-3293 Op. Fa~c: Rep.: Jeff Rea Field/Unit & Well No.: MPS~7 PTD ~~tY-029~33550 Operation: D~ig: Test: lnitial. x Test Pressure: Rams: 250/200Q MISC. INSPECTIONS: Test R+es~lt Location Gen_: P Wep Sign Housekeeping: P Drl. Rig PTD On Location P Hazard ~ec. Standing Order Posted P BOP STACK: QuanMy Size Test Result Annular Preventer 2 2 9/7S 5000 P Pipe Rams 1 1"X ~ 9J96 5A- P Lower Pipe Rams Blind Rams 2 3-1t8" gate v P Choke Ln. Valves 2 21d16" 5000 P HCR Valves Kill Line Valves 2 2 1li6" 5000 P Check Valve MUD SYSTEM: V~sual Test AiaRn Test Trip Tank NA Pit Level Indicators NA Flow Indicator NA Meth Gas Detector NA H2S Gas Detector FP 1Al~cover: Weeidy: Anrrular. 250f2QOQ TEST DATA Test Rest~lt Explor-: B~-Weekly Valves: 250/2000 ~c~vwer Kelly 0 NA 8aii Tyrpe 0 NA Ir~ide BOP 0 FP FLOOR SAFETY VALVES: Quantity Test Result U~per Keily 0 NA CHOKE MANIFOLD: Quantity Test Result N+~, Vaives 3 P M1a~~ Chokes 1 P H~yci~auTie Chokes 0 NA /kCCUMt~LAFOR SYSTEM: TrmefPressure Test Result Systern Pressure F~es~e After Cl~osure 2Qfl psa At#ained Fe~ Pr-e~re Attained BNnd Sw`tch Covers: All stafions NA I~ita~n. Battt~s (avg): NONE Test ft~su~ts Number of Failures: 1 T~st Time: 3A Hcuus Cocn¢onents tested ALL Repair or replacemerrt af equipmerrt wif( be made within days. Notify the North Slope Inspector 659-3607, fo{low w~th wriEten confirmation to Supervises at: Remarks: Weatherford Gok2od BOP 2 9116" ~ck eortfic~uratian tested v~h 'E" test joint. Bottom annular failed at hiqh pressure. Aaalied heat and retes# to 2000 psi tPa~ed). 24 HOUR NOTlCE G1VEN YES x NtJ~ ~ Date 1t~/(~4/~8 Time 17~00 start 10:35 Fir~ish 1f~'aived By Jeff Jones Witness BOP Test (for rigs) BFL 11/14/07 BOP Test MPS - 37 10-05-08.x1s ~ ~ MEMORANDUM State of Alaska TO: Jim Regg ' ~ `~~~f~ P. I. Supervisor ~ Alaska Oil and Gas Conservation Commission DATE: September 22, 2008 FROM: Chuck Scheve, Petroleum Inspector SUBJECT: No Flow Milne Point Unit S-37 P; ,~ 2~~-052 Monday, September 22, 2008: I traveled to BPXs Milne Point Unit and witnessed a no- flow test on well S-37. I arrived on location and found the weli shut in with 90 psi on the tubing and 70 psi on the inner annulus. The tubing, which is believed to be plugged, bled of rapidly (gas) when opened to atmosphere with no measurable flow of gas or liquid. The tubing was then shut in for 3 hours with no pressure build up noted and no flow when reopened. The annulus bled from 70 psi to 5psi rapidly and continued to flow (oil) at a rate of 3/4 gallon per minute with no noticeable increase or decrease in rate. ~ .~ S~l~v~MARY: Wetl MPU S-37 does not meet the AOGCC requirements for no flow. / . c.~~~ ~~" ~ .~ s ~ ~,~ a „~ . . STATEOFALASKA 9/9~8 ,n~ , ~ ~ ~~~~ ALASKA ~ AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND L~Q°, ,. .. . ,. ,, 1a. Well Siatus: ~ Oil. ^ Gas ^ Plugged ^ Abandoned ^ Suspended Zoa~c2s.ios zonnc2s.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well Class: , ~ Development ^ Exploratory ^ Service ^ Strati raphic 2. Operator Name: BP Exploration (Alaska) Inc. ' 5. Date Comp., Susp. or A nd 8?A o$ 12. Permit to Drill Number /~.~ 207-052 ' 308-323 / dJ~SS 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded p°o 6/10/2007 9•Z~~ 13. API Number 50-029-23355-00-00 ' 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 6/24/2007 14. Well Name and Number: MPS-37 ~ 3239 FSI, 460 FEL, SEC. 12, T12N, R10E, UM Top of Productive Horizon: 2181' FSL, 650' FWL, SEC. 7, T12N, R11 E, UM 8• KB (ft above MSL): 71.88 . Ground (ft MSL): 38.1 ' 15. Field / Pool(s): Milne Point Unit / Ugnu • Total Depth: 2026' FSL, 821' FWL, SEC. 7, T12N, R11 E, UM 9. Plug Back Depth (MD+ND) 4380 3978 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 565551 ' y- 5999905 - Zone- ASP4 10. Tota! Depth (MD+ND) - 4814 4385 ' 16. Property Designation; AD~ 380110 ~ TPI: x- 566670 y_ 5998856 Zone- ASP4 Total Depth: x- 566843 y- 5998703 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ^ Yes ~ No mi lectroni n rin inform tion e 2 C 5.05 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1800' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. CASING, LINER AND CEMENTING RECORD CASfNG< SETTWG DEPTH MD SETTING DEPTH TVD HOLE AMOUN'~ ' WT. PER FT. GRADE " TOI~ ' BOTiOM TOP BOTTOM StZE CEMEIdTING RECORO` PULLED 0" 2 H-40 rf 11 ' rF 11 ' 4" 2 Arc ic A r. - / " 4 7' -1/ ' A i 7" 2 L- 47 4' -1/ ' x I ' 23. Open to production or inject ion? ~ Yes ^ No 24. `Tus~NG RecoR~ If Yes, list each i (MD+TVD of Top 8 Bottom; Pe nterval open rforation Size and Number): $IZE ~EPTH .SET MD PACKER SET MD 5" Gun Diameter, 8 spf 3-1/2", 9.3#, L-80 4289' None MD ND MD ND 426~' - 4275~~ 3865' - 3879~ 25. ` ACID, FRACTURE, CiEMENF .SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Freeze Protected with 35 Bbls Diesel ZF). PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test: Hours Tested: PRO~ucTioN FoR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: C,n~cu~a,Teo 2a-HouR R,are OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API ~CORR~: 27. CoRe Dnrn Conventional Core(s) Acquired? ^ Yes ^ No Sidewal l Core s Ac uired? ^ Yes ^ No If Yes to either question, iist formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detaited descriptions, core chips, photographs and laboratory analytical results per 2 c~r~ti~ET~~ ~~~ DATE .j2:.~d~.:~ . , ~~~ Ui: i ~ 1L~~)N s ... __ ~~ ~ Form 10-407 Revised 02/2007 . t. °~ ,, ~ CONTINUED ON REVERSE SIDE 9. .~..~ ~~QZ~O~ ' ~ ~ ..:.~ j .. e i ~ t.~. ~ j' ,( ~ ~ .>~ . ~ . ~ ZS. GEOLOGIC MARKERS ~LIST ALL FORMATIONS AND RS ENCOUNTERED~: 29. FORMATION TESTS NAME M TVD WeIlTested. Yes ~No P~mlafrost Top SurfaCe SurFaCe If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base 2040' 1914' detailed test information per 20 AAC 25.071. TUZC 3904' 3531' UGNU MA 4125' 3739' MB1 4147' 3759' SBF2 - Top NA 4377' 3975' SBF1 - Top NB 4403' 3999' Top NC 4435' 4029' Top NE 4447' 4040' Top NF 4502' 4092' TSBD - Top OA 4538' 4126' Base OA/TSBC 4570' 4156' TSBB - Top OB 4597' 4181' SBA5 - Base OB 4624' 4206' Formation at Total Depth (Name): Schrader Bluff 4377' 3975' 30. List of Attachments: Summary of Daily Drilling Reports, Operational Summary and a Well Schematic Diagram. 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. Signed Sondra tewman Title DrillingTechnologist Date ~~ ~~~ M PS-37 207-052 308-323 Prepared By Name/Number. Sondra Stewman, 5644750 Well Number Permi o/ r v I N . Drilling Engineer: paul Hanson, 564-4195 INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diag~am with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 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. IreM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. ITe~a 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). Irenn 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITeM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and artalytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only S-37 CHOPS Compl Drive Head: Grenco D2100, 40 Hp 8" Motor sheave, 14" Drive Sheave Production Flow Tee: FMC 11" 5M x 3-1/8" 3M top and outlet flanges Wellhead: 11" x 3 1/2" FMC Gen V Tubing Hanger, TC-il t&b threads, 3" CIW `H' BPV profile . 20" welded/insulated~ 106' 91.1 ppf, H-40 9-5/8" 40#/ft., L-80 BTC 3857` KOP (c~ 500` Max Hole Angle = 34 deg. f/ 2700' to 3000' Hole angle through perts. = 20 deg. DLS = 5.5 deg/100' ~ 1386' Tbg x rod annular capacity: 0.0077 bpf IA capcity: 0.0264 bpf 3 1/2" 9.3 ppf, L-80, EUE 8rd Tubing (drift ID = 2.867", cap. = 0.0087 bpf) Volant MLT Torque rings in tubing couplings 7° 26#/ft., L-80, BTC, production Csg (drift ID = 6.151", cap. = 0.0383 bpf) 1" OD round Corod 3.5" 9.3# L80 EUE 8rd tbg with Torque rings Perforation Summarv Ref. Loa SLB Natural GR Loa 26-Jun-07 Size SPF Interval (ND) 5" PF 5008 8 4260-4275' 3865'-3879' 4.5" PJ 5 4260-4275` 3865'-3879' 4505 "XXXXX Jet Charges @ 60 deg. phasing° DATE I REV. BY 6/29/07 Hulme 8/26/08 McLellan COMMENTS Drill and csq set - D-14 Nabors 3S completion ~~ton Orig. DF Elev. = 71.88` (D-14) Orig. GL Elev. = 38.10' (D-14) DF to Csg Spool = 32.61' (D-14) Polished rod 1-1/4" OD x 40' long 7" ES Cementer Heat Trace Cable 3372` 3455` ***No MeOH or Diesel in well due #o risk of swelling elastomer in pump stator*** SLB 0.433" Encapsulated TEC wire 3953' Tbg Drain Sub, 4320 psi Corod Shear Tool, 30K # 3944` SLB TEC Gauge carrier 4224` MD 3831'TVD 1 jt 3-1/2" Boronized tbg 4233` WFD 82-8000 PCP 4265` w/ 21 ` rotor B Sl tt d T 4284` e ag ar o Centralizer 6.0" OD 4286` 7" Baffle Adapter (PBTD) 4380~ 7" float collar 4442` 7" float shoe 4794' MILNE POINT UNIT WELL MPS-37 API NO. 50-029-233550-00 BP EXPLORATION (AK~ Page 1 ~of 3 VWell: MPS-37 Well History Well Date MPS-37 7/27/2008 MPS-37 7/31/2008 MPS-37 7/31/2008 MPS-37 8/1/2008 MPS-37 8/1/2008 MPS-37 8/1/2008 MPS-37 8/1/2008 M PS-37 M PS-37 MPS-37 MPS-37 M PS-37 MPS-37 MPS-37 MPS-37 M PS-37 M PS-37 8/2/2008 8/3/2008 8/4/2008 8/5/2008 8/6/2008 8/7/2008 8/8/2008 8/9/2008 8/10/2008 8/11 /2008 MPS-37 8/12/2008 MPS-37 8/12/2008 MPS-37 8/13/2008 MPS-37 8/13/2008 MPS-37 8/14/2008 MPS-37 8/15/2008 MPS-37 8/15/2008 M PS-37 MPS-37 8/15/2008 8/15/2008 MPS-37 M PS-37 MPS-37 MPS-37 MPS-37 8/16/2008 8/16/2008 8/17/2008 8/18/2008 8/19/2008 • • Summary ASRC Test Unit #1, Move unit to L-201, Sim Ops issues with CTU, Move unit to Price Pad for maintenance, start prep for CHOPS job ASRC Unit #1 prep for CHOPS "job in progress'" CTU # 6, Swap wellbore fluid, Travel from E-29 to MPS-37. Move in and rig up iron. Go weather Standby. CTU #6 1.75" CT End weather STBY. RIH w/ nozzle & stinger to swap well over from 9.4 ppg to 8.8 ppg brine. ~igverse out 9,~nb brine with 100 bbls of 8.8 ~~q brine. Freeze orotect tubina to 2500' with Diesel., RDMO.... *"Job complete"" ASRC Test Unit #1, Continue unit maintenance modifications for CHOPS, "'Job in progress*" Assist CTU T/I/0=0/160/0 Pump 22 bbls Diesel through tubing while taking returns up CTU. FWHP=O/250/0 Left well with CTU on well. CTU #6 1.75" CT End weather STBY. RIH w/ nozzle & stinger to swap well over from 9.4 ppb to 8.8 ppb brine. Reverse out 9.4 ppb brine """""Job in progress""""" ASRC Unit #1, prep unit for CHOPS '*job in progress"` ASRC Unit #2, prep for CHOPS "job in progress" ASRC Unit #1, prep for CHOPS "job in progress" ASRC Unit #1, prep for chops "*job in progress'* ASRC Unit #1, prep for CHOPS'"job in progress"' ASRC Unit #1, prep for CHOPS "job in progress" ASRC Unit #1, Prep for CHOPS, *'job in progress" ASRC Unit #1 MIRU tanks and unit hardline "job in progress" ASRC Unit #1 continue to rig up job, '*Job in progress" ASRC Unit #1, continue to rig up inlet, stand by for ATP meeting "job in progress" "'SURFACE WORK NABORS 3S"' SET 1.5" RK-SPMG(#4139) IN SPM ON SURFACE {BATTERY ENGAGED 01:29, 08-12-08) '"'MARKED MANDREL, AN~f Fb~iMED RIG REP OF STATUS'"' Standby to pressure test hardline for Test Unit. ASRC Unit #1 Cont. rig up and pressure test. ( PT Hardline for Test Unit / Assist Rig-3S ) T/I/0=0/0/0. Pressure test hardline to 1000 Psi. Heat 30 bbls diesel to 90' and pump down IA for pre-flush. FWHP= 0/100/20. ASRC Unit #1 continue CHOPs flowback. ( Assist Rig 3S ) T/I/0 = 54/0/0 Heat and pump 152 bbls 2% KCL water C~ 140' down IA to circ out well. FWHP=50/200/0 T/I/0=280/450/0. (Circ-out IA) Pump 165 bbis 2% KCL @ 160* down IA to circ-out well for clean-up. FW H P=200/0/0. ASRC Unit #1 continues CHOPs F/B. T/I/0=900/500/480. (Brine returns from MPS-37). Pump 278 bbls brine returns from MPS-37 flowback down tbg for disposal. FWHP=900/260/400. ASRC Unit #1 Continue CHOPs project. Flush IA w/ 30 bbis diesel heated to 110' for clean-up. ASRC Unit #1 continues with CHOPs project. ASRC Unit #1 continues with CHOPs project. ASRC Test Unit #1, Continue CHOPS project, "'Job in progress"' Page 2 of 3 ~ • MFS-37 8/20/2008 ASRC Test Unit #1, Continue S/B for well completion, *"Job in progress*'" MPS-37 8/21/2008 ASRC Test Unit #1, Continue S/B for completion, R/U line heater, divert well thru test sep, **"Job in progress'** MPS-37 8/22/2008 ASRC Test Unit #1, Continue CHOPS flowback, ""Job in progress"" MPS-37 8/23/2008 ASRC Test Unit, Continue CHOPS flowback, "'Job in progress"' MPS-37 8/23/2008 T/I/0=0/0/0. (Flush tubing) Pumped 52 bbls Water down tubing to help reset drive rod. Continued on 08- 24-08 AWGRS. MPS-37 8/24/2008 T/I/0= 0/0/0 (Flush tubing) Continued from 08-23-08 AWGRS. Pumped 1 bbl Dead Crude to attempt to help with setting corod. FWHP=O/0/0 MPS-37 8/24/2008 ASRC Test Unit #1, Continue CHOPS project, S/B for motor issues, *"Job in progress*" MPS-37 8/25/2008 ASRC Test Unit #1, S/B Pump motor issues,j*" Job in progress"" MPS-37 8/26/2008 "'*MOVE POLISH ROD'~" CYCLED POLISH ROD TWICE, GAINED A 1/2" OF POLISH ROD STICKING OUT AFTER SECOND *'~JOB COMPLETE'** MPS-37 8/26/2008 ASRC Unit #1, standby, pump motor issues *"job in progress" MPS-37 8/26/2008 Freeze protect surtace lines. Load Crude for job. Continued on OS-27-08 WSR. MPS-37 8/27/2008 ASRC Unit #1, standby, pump issues ~*job in progress'* MPS-37 8/27/2008 Freeze protect surtace lines. Continued from 08-26-08 WSR. Pumped 5 bbls Dead Crude down surface hardlines to tank. MPS-37 8/28/2008 ASRC Unit #1, standby, pump issues '*job in progress"' MPS-37 8/29/2008 "Stroke Polished Rod" Cycled polished rod up and down twice to prevent seal swelling. No change in rod position after cycles were completed. IA FL C~3 220' MPS-37 8/29/2008 ASRC Unit #1, standby, pump issues '*job in progress" MPS-37 8/30/2008 T/I/O = 3/140/0. Pull Roior from Stator, Circ, and reset Rotor. RU Weatherford crane to oolished rod cao and oulled rotor from stator, Pumped viscosified 8.8 ppg 2% KCUNaCI brine (>100cp at 60F and YP>20) down the tubing taking returns up the IA, (See pump report). "'Cont'd on 08-31-08 WSR"' MPS-37 8/30/2008 ASRC Unit #1, taking returns to tanks, LRS flushing tubing to set pump '*job in progress"' MPS-37 8/30/2008 T/I/0=4/150/0 Assist Pulling Corod/Flush By - Pumped IA w/total of 7.5 bbls 60*F 8.8 ppg 2% kcl/NaCL viscosified brine to increase & maintain BHP of 2200 psi while crane pulled corod free. Pumped 162 bbis 8.8 ppg 2% kcl/Nacl brine down tubing and take returns up IA to test unit. " Continued on 08-31-08 AWGRS" MPS-37 8/31/2008 ASRC Unit #1, taking well returns to tanks, ramping up pump **job in progress" MPS-37 8/31/2008 Assist W/ Flush Continued from 08-30-08 AWGRS. Pumped remaining 84 bbls 8.8 ppg KCUNaCL Brine down tubing while tanking returns up IA to Test unit. Total of 246 bbls. FWHP= 0/40/0 MPS-37 8/31/2008 "'Continued from 08-30-08 WSR*'* Circulate, Reset Rotor Finished circulating 246 bbls 8.8 Viscosified Brine Reset Rotor well to ASRC Test unit ~"Job Complete"' MPS-37 9/1/2008 ASRC Unit #1, continue flow well to tanks "`job in progress*' MPS-37 9/2/2008 ASRC Unit #1, flow well to tanks "job in progress" MPS-37 9/3/2008 ASRC Unit #1, flow well to tanks "job in progress" MPS-37 9/4/2008 ASRC Unit #1, flow well to tanks "job in progress" MPS-37 9/5/2008 ASRC Unit #1, flow well to tanks "job in progress" MPS-37 9/6/2008 ASRC Unit #1, flow well to tanks "job in progress"' MPS-37 9/6/2008 ( Heat Tank ) Load Fluids / Job delayed MPS-37 9/6/2008 Circulate water through heating coils on open top tank to warm heavy oil. ( Awgers continued on 09-07- , 08 ) Page 3 ~of 3 ~ ~ MF~S-37 9/7/2008 ASRC Unit #1, flow well to tanks "job in progress*' MPS-37 9/7/2008 Awgers continued from 09-06-08 Circulate Hot source water thru open top tank coil to heat tank fluids. MPS-37 9/8/2008 ASRC Unit #1, flow well to tanks '*job in progress*' MPS-37 9/9/2008 ASRC Unit #1 continues with CHOPs project. MPS-37 9/9/2008 Assist HOT operations. Pumped 94 bbls 100'F brine down IA to flush sand from perts. MPS-37 9/9/2008 ( Heat Flowback Tank) Load Source and transport to MPS-37.( Awgers continued on 09-10-08 ) MPS-37 9/10/2008 ASRC Unit #1 Continue CHOPS flowback. MPS-37 9/10/2008 Circulate hot water in coils on Tankco tank. MPS-37 9/11/2008 ( Heat open top Tank for Chops program ) Pump off source water @ MPB-50. MPS-37 9/11/2008 ASRC Unit #1 continues with CHOPS project. MPS-37 9/12/2008 ASRC Unit#1, Continue CHOPS project. MPS-37 9/12/2008 Heat Tankco tank. MIRU to well. T/1=0/0. (Perf clean-out) Load IA w/ 72 bbls water until BHP=1925 psi. Shutdown. Monitor BHP. Pump 8 bbls water for perf pulse clean-out. T/0=0/0 MPS-37 9/13/2008 ATTEMPT TO FREE STUCK COROD WITHOUT SUCCESS PUMPED 32 BBLS 8.8 PPG KCUNACL VISCOSIFIED BRINE DOWN IA TO ASSIST IN PULLING COROD WHILE APPLYING PULLING FORCE UP TO 38,000 LBS MAX WITH CRANE.'*"WELL SECURED FOR THE NIGHT"" MPS-37 9/13/2008 T/I/0=0/0/0. (Flush tbg/Assist w/ corod pull-out) Pump 32 bbls brine down tbg in attempt to free up corod. FWHP=O/0/0. MPS37 9/13/2008 ASRC Unit #1 continues with CHOPS project. MPS-37 9/14/2008 Free stuck corod and Troubleshoot suspected sand bridqe in tubing, See LRS WSR for detailed pump report. Corod is turninq freely but has possibly parted downhole~ Secure well for night, Continue eva uation~ 57~570$- MPS-37 9/14/2008 ( Heat Chops Flowback Tank ) MPS-37 9/14/2008 T/I/0=0/0/0. (Free corod). Pump 70 bbls crude C 100~ down IA to attempt to free corod. Corod came y free. The pump started turninp. Pump 19 bbls crude down IA at min. rate to maintain BHP. MPS-37 9/14/2008 ASRC Unit #1 Continue CHOPS project. MPS-37 9/15/2008 ASRC Unit #1 Continue CHOPS project. MPS-37 9/15/2008 Freeze protect).T/I/0=0/0/0. Attempt to freeze protect tbg. 7bg pressured up to 2000 psi. Monitor tbg pressure. Tbg pressure off 200 psi in 28 minutes. RD. FWHP=O/0/0. MPS-37 9/15/2008 ( Flush Test Unit Hardline ) Heat Diesel to 90' and flush Hard Line. Awgers continued on 09-16-08. MPS-37 9/16/2008 ( Flush Test Unit ) Heat diesel to 90* and flush Hardline. MPS-37 9/16/2008 Test Unit #1, RDMO, Move unit to washbay for vessel cleanout, Move line heater to L-pad, Continue maintenance, ""Job in progress*" MPS-37 9/16/2008 Circulate hot water thru coils in Tankco tank. Print Date: 9/17/2008 Page 1 of 1 ~ ~ Qperations ~ Legal Well Name: MPS-37 Common Well Name: MPS-37 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 3S p Page 1 0 mmary Report Spud Date: 6/11l2007 Start: 8/8/2008 End: 8/22/2008 Rig Release: 8/22/2008 Rig Number: 3S ' date From - To Hours Task GQde NPT Phase Description of Operations 8/9/2008 12:00 - 19:00 7.00 RIGD OTHCMP Rig released on MPK-33. Rig down and prep for rig move 19:00 - 20:30 1.50 RIGD OTHCMP Move Rig from MPK to MPS pad. 20:30 - 00:00 3.50 RIGD PRE MIRU on MPS-37 8/10/2008 00:00 - 04:00 4.00 RIGU P PRE MIRU on MPS-37. Position camp and support equipment. Spot rig. Connect rig modules. Raise and scope Derrick. 04:00 - 06:00 2.00 RIGU P DECOMP Acceot ria ~ 04:00., Rig up hardline to tree and return tank. 06:00 - 07:00 I 1.00 I KILL ~ P 07:00 - 10:00 I 3.00 I KILL I P 10:00 - 11:30 I 1.50I WHSUR I P 11:30 - 13:00 I 1.50 I W HSU R I P 13:00 - 18:00 5.00 WHSUR P 18:00 - 18:30 0.50 WHSUR P 18:30 - 22:30 4.00 WHSUR P 22:30 - 23:30 1.00 WHSUR P 23:30 - 00:00 0.50 PULL P 8/11/2008 00:00 - 01:30 1.50 PULL P 01:30 - 02:00 0.50 PULL P 02:00 - 05:30 I 3.501 PULL I P DECOMP Pressure test hardline- 500 psi to tank, 3500 psi to closed choke. PJSM, Crew meeting to discuss scope of project, and expectations. DECOMP Circulate 85 Bbls of diesel to tiger tank. Clrculate until clean 8.8 #/gal brine returns (total of 130 Bls). Blow down line to tank. RU and circulate 250 Bls of 130 deg F, 8.8 3/gal NaCU2% KCL to warm u well bore. DECOMP Suck out tree. Dry rod TWC. Test to 1000 si from below for : minutes. Test to psi rom above for 5 minutes. Both tesl charted. RD circ lines from tree. DECOMP ND tree. Check tubing hanger threads / 3-1/2" TC-II. Unable to MU XO completely due to shoulder on XO. DECOMP NU DSA. PU and NU BOPE DECOMP Fill BOPE and fur~ction BOPE com onent . DECOMP Pressure test to 250 / 3500 psi against the TWC with 3-1/2" test joint, 2-7/8" X 5" VBR, per BP/AOGCC Regulations. Test witnessed by NAD toolpusher and BP/ WSL. The State's right to witness the test was waived by Chuck Scheve at 15:00 hrs on 8/10/2008. DECOMP M/U shootin i . TWC, 0 psi on OA, UD lubricator and shooting nipple. DECOMP M/U landing joint with 3-1/2" TCII XO. DECOMP Circulate 300 bbls heated 8.8 ppg Nacl at 157 spm / 110 psi. DECOMP Pull tubing hanger free with 32K, and LD hanger and landing joint. DECOMP POH / LD 3-1/2" IBT tubing with protectors while circulating 05:30 - 06:00 0.50 PULL P DECOMP Clear and clean rig floor, Rabbit and strap 3-1/2" pup joints. 06:00 - 08:00 2.00 PERFO P OTHCMP PJSM. PUMU 4.75" magnet w/ 15' of 5" Powerflow 5008 guns, 8 spf, 135/45 deg phasing, .98" entry hole, 9" penetration / eFire head / ported sub / 15' of 4.5" PJ 4505, 5 spf, 72 deg phasing, .45" entry hole, 54" penetration / CBF ball drop fireing head / Hyd disconnect / 1 full jt of 3-12" tubing / 10' put jt / 1 full jt 3-1/2" tubing / 2 ea 10' pups / 3-1/2" EUE 8 Rd, 9.3 #/ft tubing to surface. Use Best-O-Live pipe dope and torque to 3000 ft-Ibs. 08:00 - 13:30 5.50 PERFO P OTHCMP RIH with perf puns. RIH to 433Q, Lay down single. Total full jts - 134. PUW of 48K / SOW of 38K 13:30 - 16:30 3.00 PERFO P OTHCMP PJSM w/ SLB e-line. RU SLB equipment to Rig floor and pipe shed. PUMU 1-11/16" GR/CCL with weight bar. RIH and tie in with log SLB Natural Gamma Ray dated 26-Jun-2007. Depth correction calculate (+6.5') POH 16:30 - 17:30 1.00 PERFO P OTHCMP Rig down SLB e-line. PJSM with crew for firing TCP guns 17:30 - 18:00 0.50 PERFO P OTHCMP PU space out pups and 1 single of 3-1/2" tubing. RIH marking pipe for depth adjustments. Printed: 9/8/2008 11:15:48 AM ~ • 'BP , Page 2 of 7 C?peratian,s Summary Report Legal Well Name: MPS-37 Common Weil Name: MPS-37 Spud Date: 6/11/2007 Event Name: WORKOVER Start: 8/8/2008 End: 8/22/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/22/2008 Rig Name: NABORS 3S Rig Number: 3S "° Date From - Ta Hours Task Code NPT Phase ' Qescription af Qperations 8/11/2008 18:00 - 20:30 2.50 PERFO P OTHCMP Circulat to clear air from string. Close annular and pump down Tubin and IA observed guns fired ~ 4,260'-4,275' , bleed off tubing and IA with 0 pressure or losses, OA=O psi, close annular and pressure up on IA to 400 psi, pumps off in 4 minutes bleed to 180 psi. Drop ball, close annular and circulate down tubing through choke to pits, ball on seat, close choke and observed guns fired with 3,250 psi ~ 4,260'-4,275', bleed to 0 psi. observe no losses. POW = 48K, SOW = 38K. 20:30 - 21:30 1.00 PERFO P OTHCMP Circulate 150 bbls 8.8 ppg Nacl -2% KCL 3 bpm / 280 psi with no losses. Shut in and pressure up IA to 400 psi, pumps off in 4 minutes bleed to 160 psi. 21:30 - 00:00 2.50 PERFO P OTHCMP POH from 4,275' MD, UD one joint and 2 pups, standing 3-1/2" tubing in Derrick, stop at the guns and held PJSM with Schlumberger gun crew. 8/12/2008 00:00 - 02:30 2.50 PERFO P OTHCMP BO/LD Perf-guns, ball was recovered, all shots fired (196 total). - 4 cups fine metal and small pellets from gun debri recovered from string magnet. 02:30 - 03:00 0.50 PUWOR RUNCMP Clean and clear rig floor, PJSM. 03:00 - 06:00 3.00 RUNCO RUNCMP RIH with mule shoe, GLM, X-nipple 67 stands 3-1/2" tubing from Derrick, 40 stands in at 05:30 hours. 06:00 - 09:00 3.00 RUNCO RUNCMP RIH 134 joints and space out pups to position Muleshoe ~ 4287'. PUMU hanger. PUW 47K, SOW 37K. Land tubing. RILDS. Dry rod TWC. Test to 3500 psi for 5 minutes and chart. 09:00 - 12:30 3.50 RUNCO RUNCMP Suck stack dry. ND BOPE. Viscosify pits with Flo-Vis plus (170 Bis) 12:30 - 16:00 3.50 RUNCO RUNCMP NU tubing head adaptor. Position Flowback tree w/ ASRC assisting in positioning tree. Test tubing head adaptor to 5000 psi for 20 minutes. Test tree to 5000 psi for 10 minutes and chart. MIRU SLB N2 and qumpinq equipment. 16:00 - 22:00 6.00 RUNCO RUNCMP RU kill line and test to 3,500 psi. RU line from cellar to Tiger tank. Schlumberger and ASRC crews, RU lines to Tree and flow back equipment. 22:00 - 22:30 0.50 RUNCO RUNCMP ' at t 500 si MP I TWC, tubin on a Vac OA = 0 si. 22:30 - 00:00 1.50 RUNCO RUNCMP Wait on ASRC crew change out and off site safety training. Rig crew perform house cleaning. 8/13/2008 00:00 - 02:30 2.50 CLEAN P CLEAN Wait on ASRC crew attending off site safety training. Rig crew perform house cleaning. 02:30 - 03:00 0.50 CLEAN P CLEAN Held pre-spud meeting with Schlumberger, ASRC, little Red, Pad OPS, Pilot OPS Team Leader and Rig Supv. 03:00 - 04:30 1.50 CLEAN P CLEAN Pressure test Nitrogen hard lines with N2 to 3,500 psi. Pump test SLB chemical injection skid. Test hardline to 3500 psi with triplex (liquid leg) 04:30 - 06:00 1.50 CLEAN P CLEAN Pressure test ASRC hard lines to 1,000 psi. Repair leaks 06:00 - 09:00 3.00 CLEAN P CLEAN Shoot fluid lev I in IA. FL ~ 3-40". al i. Send ASRC to get another block valve for iron downstream of separator (to tanks). Change block valve and PT to 1000 psi. Shoot another FL down tubing, confirm fluid level ~ 30-40'. 09:00 - 10:00 1.00 CLEAN P CLEAN LRS go to load 30 Bbis of diesel. Re-check rig up and operational procedure. PJSM 10:00 - 11:00 1.00 CLEAN P CLEAN LRS on location. Pre-heat diesel on location. MIRU LRS. 11:00 - 11:30 0.50 CLEAN P CLEAN Open well to ASRC. Test line to 1000 psi. Open IA and Pump Printed: 9/8/2008 11:15:48 AM ~ ~ BP Page 3 of 7 Qperatic~ns Summary Report Legal Well Name: MPS-37 Common Well Name: MPS-37 Spud Date: 6/11/2007 Event Name: WORKOVER Start: 8/8/2008 End: 8/22/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/22/2008 Rig Name: NABORS 3S Rig Number: 3S Date From - To Hours Task Code NPT Phase Descripti4n of Qperatior~s 8/13/2008 11:00 - 11:30 0.50 CLEAN P CLEAN 30 Bbl of 90 deg diesel @ 1.7 BPM, 360 psi. 30 Bbls returns. 11:30 - 12:30 I 1.00 I CLEAN I P 12:30 - 14:30 i 2.00 I CLEAN I P 8/14/2008 100:00 - 06~ 0 6.00 CLEAN P 06:00 - 12:00 I 6.001 CLEAN I P 12:00 - 18:00 I 6.00 I CLEAN I P 18:00 - 00:00 I 6.00 l CLEAN I P 8/15/2008 00:00 - 03:00 3.00 CLEAN P 03:00 - 06:00 3.00 CLEAN P 06:00 - 13:00 I 7.00 I CLEAN I P 13:00 - 15:00 I 2.00 ~ CLEAN I P 15:00 - 16:30 I 1.501 CLEAN I P RDMO LRS. CLEAN Come on line pumping 2% KCL w/ foam agent and N2 ~ 500 scf/min N2, 860 psi injection pressure. 0 psi on OA, rate thru seperator of 1.8 BPM. CLEAN Reduce N2 rate to 450 scf/min, foam rate of 13.5 gpm. With 100 Bbls total fluid pumped, increase pressure to 200 psi at flowback choke. Treating pressure to 1195 psi. Diesel to surtace C~ 13:45. Foam to surface ~ 14:15. Seperator "slammed" w/ gas-foam. Divert gas to gas return tank and liquids and solids to another tank. Regulate Choke pressure to 100 psi. Max N2 pressure on injection side / 1244 psi. Drop to 650 psi as regulate seperator. CLEAN Reduce N2 rate to 350 scf/m, foam agent ~ 13.5 gpm. CLEAN N2 rate to 350 scf/m, foam agent ~ 10 gpm. 03:00 hours sample = 66% oil, 22% water cut, 11 % solids. 06:00 Totals: 11,000 gal N2 used (4400 gals pumped / 6600 gals losses), 573 Bbls total fluids returned / 137 Bbls brine from wellbore / 30 bbl diesel spear, 298 bbls pumped with foam agent - N.~t fluids = 108 Bbls formation fluids recovered. CLEAN Continue foam FCO. N2 rate of 350 scf/min, foam agent ~ .5% in 2% KCL and rate of 10 gpm. Returns ~ 24 Bbls/hr / 14 Bbls hour pumped - Net flow ot 12 Bbls/Hr from formation. Solids/water cut varying as well dumps san , an is c eanmg up. CLEAN Continiue foam FCO. Maintain contstant N2 rate of 350 scf/m. Treating pressure of 750 psi. Pump foam sweeps (increase foam concentration for 50 gals) and continue cleaning out sand. Sand concentrations varying as well dumps and cleans up. CLEAN Continue foam FCO. 1% foamer, 354 scf/min , IA = 411 psi, Tubing = 77 psi 13,9 gal/min 478 bbls. 22:00 hours = 1/2% foamer, 354 scf/min, IA = 452 psi, Tubing = 104 psi, 10 gal/min 531 psi. Sand and oil concentrations continue to decline. CLEAN Continiue foam FCO. Maintain contstant N2 rate of 350 scf/m. CLEAN LRS on location, load 150 Bbls 2% KCL from upright source tank. Pump 140 Bbls down IA ~ 1.5 BPM, 400 psi (pump pressure), returns through ASRC seperator. Close choke, build 300 psi treating pressure (pressure ~ IA-wellhead), tubing pressure to 70 psi, wing open choke, repeaT 3 times. Total fluid pumped - 151 Bbls, - 8 Bbls into formation. CLEAN Dlsplace 140 deg F, 2% KCL w/ N2 ~ 350 scf/min, 2% KCL w/ 1% foam agent ~ 10 gpm. Treating pressure from 300 psi to 1200 psi as displace fluid from wellbore. Good foam to surface. -15% solids in returns. Pump 50 gal sweep of 2% foam agent ~ 10 gpm, w/ 350 scf/day N2. CLEAN Sweep not yet to surface, pinhole leak develop in flange body inside seperator. Secure well. RU SLB triplex pumping neat KCL to flush return lines and seperator to tanks. Add no foam as flush vessel and lines. Call for LRS. Break out valve and flange on throttling valve in seperator. Valve-flanqe body cut out. CLEAN LRS on location. Load 90 Bbl of 2% KCL from upright tank. Printed: 9/8/2008 11:15:48 AM ~ • O~erations Legal Well Name: MPS-37 Common Well Name: MPS-37 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 3S Date I From - To ( Hours I Task I Code I NPT 8/15/2008 I 15:00 - 16:30 I 1.501 CLEAN I P CLE ~ry Report Spud Date: 6/11 /2007 Start: 8/8/2008 End: 8/22/2008 Rig Release: 8/22/2008 Rig Number: 3S ~se Description of Qperations AN Spot near rig and RU to IA. Test lines to 2000 psi. Open well to 450 psi on IA / 253 psi on IA. Come on line pumping 2 BPM, 160 deg F with 2% KCL. AN Clrculate 160 Bbls heated, 160 deg F, 2% KCL down annulus, returns through 3" choke skid, bypass seperator. With 140 Bbls pumped, running squeeze Hot KCL into formation by closing choke, building 450 psi WHP / 150 psi Tbg pressure then opening choke. Repeat 3 times. - 8 Bbls into formation. RD LRS. AN Start foaming again with 1% foam, 10 gpm. 350 scf / min N2. Hold - 100 psi on choke skid. (Seperator is bypassed). Pump 50 gal sweep of 2% foam agent ~ 10 gpm, 350 scf / min N2. S~zstantial amount of solds returned with initial foam returns. 16:30 - 18:00 I 1.501 CLEAN I P I I CLE 18:00 - 00:00 I 6.00 I CLEAN I P I I CLE 8/16/2008 I 00:00 - 02:00 I 2.00 I CLEAN I P 02:00 - 02:30 0.50 CLEAN P 02:30 - 04:00 1.50 CLEAN P 04:00 - 06:00 I 2.001 CLEAN I P 06:00 - 09:30 I 3.50 I CLEAN I P 09:30 - 11:30 I 2.00 I CLEAN I P 11:30 - 14:30 I 3.00 I CLEAN I P 14:30 - 15:00 I 0.501 W HSU R I P CLEAN Continue to displace 50 gal sweep of 2% foam agent, with 1% foam agent ~ 10 gpm, 350 scf / min N2, surface to surface. Shut in Well. CLEAN RD Schlumberger and RU to displace. CLEAN Displace well with rig pump at 2 bpm / 500 psi to 8.8 ppg Nacl + 2% Vis / KCL, 180 bbls through the choke skid to the storage tanks. CLEAN Position Vac trucks to ASRC storage tanks, and fill pits with 8.8 Nacl + 2% Vis / KCL. Check WHP's. 500 psi on IA, 50 psi on tubing. CLEAN MIRU LRS, Pump 30 Bbis of 110 deg F diesel down IA, returns through choke and ASRC equipment. With diesel at surtace, reduce rate to 1/2 BPM to flush ASRC equipment. Pumped total of 175 Bbls of viscosified brine. CLEAN Blow down ASRC hardline. RD ASRC equipment. RU for circulate and kill well. CLEAN O en well to 510 si on IA 120 si on tubin . Bleed as thru asQ bu.sler, come on line pumping 2% KCI-8.8 #/gal NaCL-Viscosified. Circulate down tubing returns from IA. Circulate 300 Bbls, losses ~ 28 Bls/Hr. Flowcheck well for 1 hour. DECOMP D rod TWC. Test from abov to 3 15:00 - 16:30 1.50 WHSUR P DECOMP ND tree. Bleed hanger void. Inspect top hanger threads. 16:30 - 20:00 3.50 WHSUR P DECOMP NU 13-5/8" BOPE. 20:00 - 21:00 1.00 WHSUR P DECOMP Fill BOPE and function BOPE components. Grease choke and BOP valves. 21:00 - 00:00 3.00 WHSUR P DECOMP Pressure test to 250 / 3500 si a ainst the TWC with 3-1/2" test'oint, 2-7/8" X 5" VBR, per BP/AOGCC Regulations. Test witnessed by NAD toolpusher and BP/ WSL. The State's right to witness the test was waived by Chuck Scheve at 15:00 hrs on 8/16/2008. 8/17/2008 100:00 - 01:30 I 1.501 WHSUR I P I I DECOMP TWC, 0 psi on OA, IA is on a Vac, UD lubricator and shooting nipple. 01:30 - 03:00 1.50 WHSUR P DECOMP M/U landing joint with 3-1/2" TCII XO. FMC well head tech BOLDS, pul! tubing hanger free with 45K, SOW = 32K and LD hanger and landing joint. PU single 3-1/2" tubing, RIH to tag ~ 4295' MD. PU to FCO cleanout deoth of 4286'. Printed: 9/8/2008 11:15:48 AM ~ • ~ p Page 5 Qf 7 Uperations Summary Report . Legal Well Name: MPS-37 Common Well Name: MPS-37 Spud Date: 6/11/2007 Event Name: WORKOVER Start: 8/8/2008 End: 8/22/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/22/2008 Rig Name: NABORS 3S Rig Number: 3S Qate From - To Hours Task Code NPT Phase Description of Operations 8/17/2008 03:00 - 04:30 1.50 WHSUR P DECOMP Pump 80 Bbis down tubing 3 bpm ~ 120 psi with 8.8 ppg Nacl-2% KCL / viscosified, lost 12.5 bbls. 04:30 - 06:00 1.50 PULL P DECOMP POH LD 3 1/2" tubing. 06:00 - 12:00 6.00 PULL P DECOMP POH LD 3-1/2" workstring. Double displace tubular volume as POH. Break out jewelry and muleshoe. Secure well 12:00 - 13:00 1.00 RUNCO RUNCMP Clean and clear Rig floor. 13:00 - 16:00 3.00 RUNCO RUNCMP Load completion running equipment to Rig floor. Nabors Csg-Torque Turn, SLB "I" wire, Centrilift Heat Trace. Load Weatherford pump and completion equipment into pipe shed. 16:00 - 20:00 4.00 RUNCO RUNCMP PJSM. PUMU WFD PCP completion. 3 blade centrilizer, 3XL slotted tag bar, PCP stator, 1 jt boronized tubing, pup jt, TEC sub, pup jt. All Baker-Lok'd w/ 2280 ft-obs of torque. RIH on 8 jts of 3-1/2", 9.3 #, EUE 8 rd, L-80 w/ Volant torque rings.Torque turn all connections. MU W FD drain sub (4320 si w/ 10' pups above and below (Baker Lok'd). Continiue RIH on tubing. Run Heat Trace from bottom of jt # 24 as RIH (not including boronized jt) for 3455' of heat trace. 20:00 - 00:00 4.00 RUNCO RUNCMP Optimum torque using Volant rings calculated after 1 st 10 joints. Torqued to 3980 ft-Ibs. Sholder-up torque =~ooooc ft-Ibs. Encapsulated TEC wire run from TEC sub to surface, with Cannon cross collar clamps on every other joint. Heat Trace protected with cross collar clamps every joint, but not on hanger pup joint. Flat guards and bands the entire length. Ran - 1,200' Qt #28) at 00:00 hours. 8/18/2008 00:00 - 06:00 6.00 RUNCO RUNCMP Continue to Run 3-1/2" PCP-COROD tb Com letion wit encapsulated TEC wire and Heat Trace to surface. Centriflift perform conductiviry checks every 2,000'. Ran 58 joints at 05:30 hours. 06:00 - 12:00 6.00 RUNCO RUNCMP Continue to RIH w/ 3-1/2" L-80, 9.3#, EUE 8 rd PCP tubing completion string. Centrilift heat trace with flat guards, and SLB I-wire. Cannon cross collar clamps on every joint. Test Heat Trace cable 90 jts in hole - OK. 12:00 - 20:00 8.00 RUNCO RUNCMP Continue to RIH w/ PCP pump on 3-1/2" tubing with accessories. 20:00 - 21:00 1.00 RUNCO RUNCMP Space out with 8 ft and 10 ft pup under last joint (#133). Ran 15 Cannon cross collar clamps, 111 double cannon cross collar clamps, 252 ea flat pins, 1750 steel bands, 10 ea 3ft, 80 ea 4ft, 432 ea 6ft Flat guards. 21:00 - 22:00 1.00 RUNCO RUNCMP MU landing joint, tubing hanger and 2 ft pup. Use slimhole TC-II XO-landing joint for hanger. (close tolerances w/ penetrator and I-wire). 22:00 - 00:00 2.00 RUNCO RUNCMP FMC well head techs install Heat Trace Penetrator, Schlumberger MU I-wire to hanger, Centrilift techs make pig tail splice. 8/19/2008 00:00 - 01:00 1.00 RUNCO RUNCMP Centrilift techs finish pig tail splice and conductivity test - OK 01:00 - 01:30 0.50 RUNCO RUNCMP Land 3-1/2" completion assembly at 4,288' MD, with TWC, PUW = 55K, SOW = 40K, FMC Rep RILDS. LD landing joint. 01:30 - 02:00 0.50 RUNCO RUNCMP Tested 3" Type H TWC to 3,500 psi from above for 5 charted minutes. 02:00 - 03:00 1.00 RUNCO RUNCMP LD completion running tools and equiment. 03:00 - 09:00 6.00 RUNCO RUNCMP LOTO accumulator unit. ND 13-5/8" BOPE. Place on cradle stump, lay down BOPE. 09:00 - 13:00 4.00 RUNCO RUNCMP NU Wellhead. Tubing spool with heat trace penetrator, I wire, Printetl: 9/8/2008 11:15:48 AM ~ • BP Page 6 qf 7' Q~erations Summary Report Legal Well Name: MPS-37 Common Well Name: MPS-37 Spud Date: 6/11/2007 Event Name: WORKOVER Start: 8/8/2008 End: 8/22/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/22/2008 Rig Name: NABORS 3S Rig Number: 3S Qate From - To Hours Task Code NPT Phase ' Description of Operations 8/19/2008 09:00 - 13:00 4.00 RUNCO RUNCMP Radigan wellhead (with rod rams), 3-1/8" 5000 psi master valve. DSA's on out et spoo s o we ea ps~ x psi). Dou le valve on integral for testing, blinded on opposite side. NU choke fine to double valves on IA. 13:00 - 15:00 2.00 RUNCO RUNCMP Test Wellhead: 200 psi low / 2000 psi high (against TWC). Chart test. Final checks on I- Wire: 1733 / 1736 psi - 69 deg F. Final check on Heat Trace: 3.8 phase to phase / 100 gig phase to ground. Pull TWC. Tb and IA on vacuum. 15:00 - 19:30 4.50 RUNCO RUNCMP NU WFD 2-9/16" BOPE. Noti John Crisp with AOGCC regarding BOPE testing. Nipple up flanges for kill line and on top of BOPE for testing. 19:30 - 20:00 0.50 RUNCO RUNCMP Function test 2-9/19" COROD BOPE, Weatherford accumulator system and remote station. 20:00 - 23:00 3.00 RUNCO RUNCMP Test 2-9/16" COROD BOPE choke and kilf fines and valves to 250 / 2,000 psi. BOPE test Witnessed by John Crisp with AOGCC. The Rig choke manifold was tested on 8/16/2008. MU Corod safery assembly and riser to rig floor between BOP test steps to aid in testing sequence. 23:00 - 23:30 0.50 RUNCO RUNCMP RD test joint and test equipment. Hook up a flow line to pits. 23:30 - 00:00 0.50 RUNCO RUNCMP Held PJSM with Weatherford COROD Team, Rig crew and HOT Lead etc. 8/20/2008 00:00 - 04:00 4.00 RUNCO RUNCMP Weatherford tecks RU Mobile Gripper Unit and hang Gripper-head on Rig blocks in Derrick, assemble Gripper Guide Arch and pin to Gripper-head. Snake COROD into Gripper-head. Work Rod Shear through Gripper-head. 04:00 - 05:30 1.50 RUNCO RUNCMP RIH with 1" Corod com letion = PCP rotor, 320' of giraffe string, rod shear, 3 719'~ of Corodi (4039') -(05:15 hours) pony rods for space out, 40 ft of polish rod, Landing rod extensions. 05:30 - 06:00 0.50 RUNCO RUNCMP RD Gripper guide arch, MG head. 06:00 - 11:30 5.50 RUNCO RUNCMP PUMU 10 ea 1" jointed sucker rods, RIH to tag and space out. Tag up 5' in on jt #10. Very slow to work rotor thru stator. Close stripping head, pressure to 500 - 700 psi and pump stator down. Tag on tag bar, PU and confirm 3 times. Lay down 3 jts and mousehole 1 jt. 11:30 - 16:30 5.00 RUNCO RUNCMP PU 2 ea 8' SR, 1 ea 2' SR, 40' polish rod, landing jt. RIH to tag Work thru stator again. Tag bar, PU 3'. Torque rams on wellhead to 400 ft-Ibs on lower ram, 600 ft-Ibs on upper ram. Test void to 2000 psi and chart. 16:30 - 17:30 1.00 RUNCO RUNCMP Rig down Corod safety, clean and clear floor. 17:30 - 20:00 2.50 RUNCO RUNCMP ND / LD Master valve, riser, kill and choke lines and valves. And remove from cellar. 20:00 - 21:30 1.50 RUNCO RUNCMP using the cellar bridge crane, with Grenco rep to the Radigan well head. Use 1" sucker landing rod and screw into rod string, FMC well head tech release lower and upper well head rams, PU Rod string 4" to space out polish rod to mate with Grenco drive head. FMC tech Torqued rams on wellhead to 400 ft-Ibs on lower ram, 600 ft-Ibs on upper ram. 21:30 - 22:00 0.50 BOPSU P RUNCMP Secure all valves and normal up Corod well head. 22:00 - 00:00 2.00 RIGD P RUNCMP RD to move Carrier off well. Scope and lower Derrick. 8/21/2008 00:00 - 05:00 5.00 RIGD P RUNCMP Jack down Carrier. Move off well MPS-37 as per BP / Heavy Oil Team , to allow for hook up of flowlines. Move off well was witnessed by Pad operator and WSL. Move carrier down Jr Printed: 9/8/2008 77:15:48AM ' ~ • __ ; gp Page Z of 7 aperations Summary Report Legal Weli Name: MPS-37 Common Well Name: MPS-37 Spud Date: 6/11/2007 Event Name: WORKOVER Start: 8/8/2008 End: 8/22/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/22/2008 Rig Name: NABORS 3S Rig Number: 3S date From - To Hours Task Gode NPT Phase Description of Qperations 8/21/2008 00:00 - 05:00 5.00 RIGD P RUNCMP location Yo allow for clearance for crane and trucks to access welihead. 05:00 - 00:00 19.00 RIGD P RUNCMP Perform light maintenance while waiting on Heavy Oil Team to hook up lines and surface fluids from well. Rig day crew attended on site Man lift training. Crews review procedures for summer maintenance tasks. CHOPS #1 was turned on just before midnight on 8/21/08. 8/22/2008 00:00 - 07:00 7.00 RIGD P RUNCMP Perform light maintenance while waiting on Heavy Oil Team to hook up lines and surface fluids from well. Welder working on , staircase inclosure in pipe shed. The well is surfacing brine and no issues with the pump. The Rig was released at 0700 hrs on 8/22/2008. ~-., Printed: 9/8/2008 11:15:48 AM r ~ = - ~; ; A]LASSA ~u Ai~TD G~S COI~TSERQATI011T COMnIISSIOI~T Dan Kara Engineering Team Leader BP E~loration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 ~ SARAH PALIN, GOVERNOR 333 W. 7thAVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Milne Point Unit, Ugnu Undefined Oil Pool, 1VIPS-37 Sundry Number: 308-323 ,., g} ~ ~ ~~ ~ Dear Nir. Kara: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Conunission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next wor~ng day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court uniess rehearing has been requested. Sincerely, ~+~ Cathy P. Foerster ~ DATED this ~Z day of September, 2008 Encl. 9~- ,~~ ~~ ~ ~ ~ ~ . ~e~ ~ STATE OF ALASKA ~? ALAS~A OIL AND GAS CONSERVATION COMMI I~O~ ~ Z~~~~ APPLICATION FOR SUNDRY~~~1~~~;~;,~, ~~;~,-;~;~~~ 20 AAC 25.280 ~,~,~syr,~~~ -~~ 1. Type of Request: ^ Abandon ^ Suspend ^ Operatiort Shutdown ^ Perforate ^ Time Extension ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ~ Other ~ See Attached 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) inc. ~ Devetopment ~^ Exploratory 207-052 ' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23355-00-00' 7. If perForating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: MPS-37- Spacing Exception Required? ^ Yes ~ No 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): , ADL 380110 71.88 Milne Point Unit / Ugnu 12• PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 4814 ' 4385 ' 4380 - 3978 ' None None a in L h i 1 e tructural r ' " 1 7 S rF 2' /" 7' 7' 7 0 309 Interm i n 1' 7" in r PerForation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4260' - 4275' 3865' - 3879' 3-1/2", 9.3# L-80 4286' Packers and SSSV Type: None Packers and SSSV MD (ft): 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal ~ BOP Sketch ^ Exploratory ~ Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: September 15, 2008 ~ Oil- ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bryan McLellan, 564-5516 Printed Name Dan K ra Title Engineering Team Leader Prepared By Name/Number: Signature `- --~^ ~(~~ Phone 564-5667 Date Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: ° Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ~BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~t~tow ~cS~ ~ pc~ aoP~l~C,~~. a~~ ~-~1 vv,~-~c~~es'r~ ~OI~~C~~~~~is~'~~~ ~G> ~ ~ e.~ ~as~~s ~,`~ ~51 <~~ ~ ~1C,~~~C~1 c~~.r.~ `~E~E vc~.~ ~,~c~s r~.cc~, ~~ N:~~~ ~c, ~~h:s C,Q ~c-c~-~. ~c~ 0 ~t~, Subsequent Form Required: ~~ ~ APPROVED BY g'~z-D~ A roved B: COMMISSIONER THECOMMISSION Date ~ O ~. ~ Form 10-403 Revised 0~/2006 Submit In Duplicate ~ , a , ~ ~ ~ ~ . ~~ ~ ~, ~ ~ ~1` A L ~: ~ ~ ~~ s~p ~ ~ ~oos ~ ~ ~ ,, ~ • ~ ° } ~ J~~ j . : ` < ~ __~ ~~ _. • MPS-37 Pulling sucker rod Scope of Work: Capital Wellwork - Pull and lay down ~43' of jointed sucker rod from the rod string. This will remove the rotor from the Progressive Cavity Pump stator, allowing for circulation and preventing the rotor from becoming stuck over planned the 6-8 month shut-in period. The attached Sundry application for this work is to request approval for secondary well control equipment under 20AAC25.288 "Well Control Requirements for Other Service Operations". MASP: 1345 psi Welf Type: Ugnu Heavy Oil Producer Estimated Start Date: September 15th, 2008 Production Engineer: Jim Young Intervention Engineer: Bryan McLellan Prouosed Procedure 1. MIRU Crane and pump truck. 2. Pick up on polished rod, pulling it 25 feet up so that the rotor pulls out of the progressive cavity pump (PCP) stator. 3. Circulate 8.8 ppg brine down the tubing, taking returns up the Inner Annulus to replace wellbore fluids with kill weight brine. 4. Lower the rotor back into the PCP stator. Close the 2 polished-rod rams on the polished rod and pressure test between them to at least 500 psi. 5. Nipple down the rotating drive head and NU BOP stack (see attached BOP stack schematic). 6. Pressure test BOP stack to 250 psi low/2000 psi high. IVote that the valves on the kil! and choke lines will be manual valves (not HCR valves), and the kill and choke lines will have hammer union connections, with the exception of the flanged gate valves directly attached to the wellhead and BOP equipment. The choke skid will consist of two manually operated chokes with a bypass. It will not be possible to pressure test the Choke line valves on the inner annulus from the well side because there is no packer in the well and the perforations are open below. The choke line valves on the IA will be tested from the choke side. 7. Pull on the polished rod with the crane. Lay down the polished rod, and ~43' of jointed sucker rods. Note that these rod connections will be broken out by 2 man crew working from a manlift or scaffolding. There will be no rig on location. 8. Pick up the polished rod and make it back up to the rod string. 9. Run the polished rod back into the well and close the polished rod rams on the rod. 10. Nipple down BOP stack. NU manual gate valve and tree cap above the polished rod. 11. Freeze protect the well with dead crude after getting pressure build-up data from the well. 12. RDMO crane and pump truck. ~ BOPE for Sucker Rod Retrieval Rigless Operation Note: BOP and Wellhead heights are approximate • Top of Anvulars 16' above GL Upper Annular preventor is only a rod wiper, vot used for well control. The upper a~mular will not be tested during the BOP test. 2 avnulars 2.65' Top of pipe ram 13.4' above GL Sized for 1" OD rod. Piperam ].90' Test Spool X/O 3-1/8" SK x 2-9/16" SK 3-1/8" SK gate valve X/O 3-I/8" 3K x 3-1/8" SK Radigan s ool cl~oke Choke Line 1.5' 1.5' 1.43' 1' 233' ~ •: I j`„ 5o0o#i-:..'i BOP test spool 2-9/16" SM Top 1 ].5' above GL Gats valve with ~o (3-1/8" SK x 2-9/16" SK) Top 8.58' above GL Radigan spool top 6.15' above GL ~~ Killline Top tubivg spool 3.80' above GL 11~S-37 Drive Head: Grenco D2100, Hp 8" Motor sheave, 14" Drive Sheave Production Flow Tee: FMC 11" 5M x 3-1/8" 3M top and outlet flanges Wellhead: 11" x 3 1/2" FMC Gen V Tubing Hanger, TC-II t&b threads, 3" CIW `H' BPV profile ~ 20" welded/insulated~ 106` 91.1 ppf, H-40 CHOPS Compl on ~j. DF Elev. = 71.88` (D-14) Orig. GL Elev. = 38.10' (D-14) DF to Csg Spool = 32.61 `(D-14) Polished rod 1-1/4" OD x 40' long 7" ES Cementer 9-5/8" 40#/ft., L-80 BTC 3857` KOP ~ 500` Max Hole Angle = 34 deg. f/ 2700' to 3000' Hole angle through perfs. = 20 deg. DLS = 5.5 deg/100' ~ 1386' Tbg x rod annular capacity: 0.0077 bpf IA capcity: 0.0264 bpf 3 1/2" 9.3 ppf, L-80, EUE 8rd Tubing (drift ID = 2.867", cap. = 0.0087 bpf) Volant MLT Torque rings in tubing couplings 7" 26#/ft., L-80, BTC, production Csg (drift ID = 6.151", cap. = 0.0383 bpf) 1" OD round Corod 3.5" 9.3# L80 EUE 8rd tbg with Torque rings ' Pertoration Summary Ref. Log SLB Natural GR Log 26-Jun-07 Size SPF Interval (ND) 5" PF 5008 8 4260-4275` 3865`-3879' 4.5" PJ 5 4260-4275' 3865`-3879' 4505 "X~CXX Jet Charges @ 60 deg. phasing" DATE I REV. BY COMMENTS Heat Trace Cable 3372` 3455` ***No MeOH or Diesel in well due to risk of swelling elastomer in pump stator*** SLB 0.433" Encapsulated TEC wire 3953` Tbg Drain Sub, 4320 psi Corod Shear Tool, 30K # 3944` SLB TEC Gauge carrier 4224` MD 3831 `TVD 1 jt 3-1/2" Boronized tbg 4233` WFD 82-8000 PCP 4265` w/ 21 ` rotor T B 4284` ag ar Slotted Centralizer 6.0" OD 4286` 7" Baffle Adapter (PBTD) 4380` 7" float collar 4442` 7" ftoat shos 4794` MILNE POINT UNIT WELL MPS-37 API NO. 50-029-233550-00 6/29/07 Hulme Drill and csg set - D-14 8/26/08 McLellan Nabors 3S completion BP EXPLORATION (AK) BOPE for pulling sucker rod . ~ Maunder, Thomas E (DOA) Page 1 of 3 From: Maunder, 7homas E (DOA) Sent: Friday, September 12, 2008 2:23 PM To: 'McLellan, Bryan J' Cc: Kara, Danny T; Young, Jim; Mathews, Wiiliam L; Engel, Harry R; Cismoski, Doug A; Regg, James B (DOA) Subject: RE: BOPE for pulling sucker rod -- MPS-37 (2Q7-052) Attachments: Na_flow_guide.pdf Brian, I am finishing my review of the proposed work plan and I will be forwarding to the Commissioners. The sundry is not likely to be issued prior to Monday, however it appears that there is some 3 days of work to be accomplished before ND/NU occurs. For your reference, I have attached a copy of the no-flow test guidance document that has been developed. An Inspector should be contacted to witness the no-flow test. It is recognized that this is likely the only well so equipped on the North Slope and some discretion is being granted regarding the choke and kill lines. Hammer unions are specificatly cited as not acceptable and hydraulically controHed choke and kill valves are specifically required in the BOP regulations. You and your cotleagues are working to prove new completion and production concepts on the Slope. As equipment becomes more standardized and available, relief from the regulatory requirements as recommended here may be less likely. It is further noted that it is unlikely that there witl be any need to circulate fluid using the choke or kill lines. Call or message with any questions. Tom Maunder, PE AOGCC From: Mcl.ellan, Bryan ] [mailto:Bryan.McLellan@bp.com] Sent: Thursday, September li, 2008 5:13 PM To: Maunder, Thomas E (DOA) Cc: Kara, Danny T; Young, ]im; Mathews, Witliam L; Engel, Harry R; Cismoski, Doug A Subject: FW: BOPE for pulling sucker rpd -- MPS-37 (20~-052) Tom, See Jim Young's note below regarding the production characteristics and fluid properties of the Ugnu oil from MPS-37. The current plan is to do a pressure build-up on the well after we shut it in. At the end of the pressure build-up would be a good time to do a no-flow test. The plan would be as follows; 1. Shut down the drive unit on Monday morning 9/15/08. 2. Pick up on the rod string with a crane to pull the rotor up out of the pump stator. At this point, BOP's are not required because the polished rod wi!! not be pu!!ed out of the stuffing box (polished rod is 40' long, rod only needs to come up 25' to pull the rotor out of the pump). The purpose of pulling the rotor out of the stator now is to avoid having sand settle out of the oil and bridge off above the pump during the pressure build up. Solids concentration in the oil has been around 10% by volume. 3. Begin acquiring pressure build-up data for 24-48 hours. 4. Conduct No Flow test. 5. Flush the well with kill weight fluid. 6. Set the rotor back in the pump stator. Close the polished rod rams in the wellhead. 7. Nipple down the drive unit. 8. Nipple up and test BOP's. 9. Pull and lay down the polished rod and ~43' of jointed sucker rod. 10. Make up the polished rod and run it in the well. Close the polished rod rams in the wellhead. 9/12/2Q08 BOPE for pulling sucker rod ~ • 11. ND BOP's. 12. NU Master valve and tree cap. We could ask the AOGCC inspector ta witness the no-flow test. Please feel free to call if you would like to discuss any of this in greater detail. Thank you, Bryan McLellan Page 2 of 3 From: Young, Jim Sent: Thursday, 5eptember li, 2008 3:56 PM To: McLellan, Bryan J Subject: RE: BOP~ for pulling sucker rod -- MPS-3~ (207-052) Oil gravity ~12AP1, GOR ~70 scf/stb. Measurements of the dead oil were >10,OOOcp at <80F and estimated live oil viscosity is ~2000cp at 1691 psi reservoir pressure & temperature of ~72F at ~3831' tvd (8.5ppg pore pressure gradient). After ~8-days on production flowing BHP was reduced to <1370psi before any pressure was observed on the annulus at surface (max observed of about 15psi with a fluid level ~1200' below the surface), which corresponds to a bubble point consistent with other fluid samples obtained from this reservoir. This means the reservoir is ~400psi undersaturated, meaning there is no free gas that can breakout of the reservoir without pumping the well. Pump bottomhole discharge pressure required to flow crude to surface at 100 BOPD is ~3000psi (1300psi over hydrostatic due to high friction in tubing, caused by >10,000 cp crude cooling on its way to surface at 100psi, 60F with heat trace in the tubing) and ~300psi drawdown on reservoir. From: McLellan, Bryan J Sent: Thursday, September 11, 2008 2:58 PM To: Young, ,lim Subject: FVII: BOPE for pulling sucker rod -- MPS-37 (207-052) Jim, See Tom's note below requesting production data. If we do the pressure build up, we'll probably want to have the AOGCC witness the no-flow test? Piease send me the supporting data this afternoon, if possible, so that Tom can approve the Sundry application by tomarrow. Thank you Bryan From: Maunder, Thomas E (pOA) [mailto:tom.maunder@alaska.gov] 5ent: Thursday, September 11, 2008 2:15 PM To: McLellan, Bryan J Cc: Jim Regg Subject: RE: BOPE for pulling sucker rod -- MPS-37 (207-052~ Bryan, I am reviewing the sundry application. While you describe the equipment set up planned, it would also be appropriate to include some of the well's performance information. Does it have any pressure, gas, did it only 9/12I2008 BOPE for pulling sucker rod Page 3 of 3 ~ ~ produce pumped? Is it possible to do a no-flow test? The demonstrated and witnessed inability af the well to have pressure or flow would be some excellent supporting data to employ the equipment you plan. I look forward to your reply. Tom Maunder, PE AOGCC From: McLellan, Bryan J [mailto:Bryan.McLellan@bp.com] S~nt: Wednesday, 5eptember iQ, 2008 8:25 AM To: Maunder, Thomas E (DOA) Subject: RE: BOPE for pulling sucker rod -- MPS-37 (207-052) Tom, I will prepare and send you a Sundry application tater today. We are hoping to complete this work next Monday, 9/15, which ! know is considerably less than the 10 day lead time for Sundry approval. Thanks, and I apalogize for the short notice. Bryan McLellan From: MaunderF Thomas E (DOA) [mailto:tom.maunder@ataska.gov] Sent: Wednesday, September 10, 200$ 8:10 AM To: McLellan, Bryan J Cc: Engel, Harry R; Cismoski, Doug A; Regg, Jarnes B(DOA) Subject: RE: BCJPE for pulling sucker rad -- MPS-37 (207-052) Bryan, A sundry would probably be the best way to convey the plans and secure the approval. I look forward to seeing the document. Tom Maunder, PE AOGCC From; Mclel{an, Bryan J [maiifi~:Bryan.McLeHan@bp.com] Sent: Tuesday, September 09, 2008 4: S0 PM To: Maunder, Thomas E (DOA) Cc: Engel, Harry R; Cismoski, Doug A Subject: BOPE for pulting sucker rad Tom, We recently completed a rod-pumped welt at Milne Point (MPS-37, 5undry # 308-245) in which the ApGCC had approved the well control equipment under 20RAC25.28$, "Well Control Requirements for Other Service Operations". We are planning to putl a section of the sucker rod out of this well. We'll be pulling the rod without a rig, just using a crane and scaffolding. This operation does not require a Sundry, however it does require approval under 20AAC25.288. In the absence of a Sundry application, how should we apply for approval to use this BOP configuration? Would an e-mail with attached BOP schematic be sufficient? Thank you, Bryan McLellan 9/12/200$ ~ ~ NaFlow Test Prvicedure and Recommended Equipment Test Procedure Artifieial lift must be shut down and the well pressure bled prior to the arrival of a Commission Inspector. After pressure is bled, the well must be lined up to an atmospheric tank or vessel capable of capturing any produced fluid during the test. A minimum 3-hour witnessed test is required. Allowable Flow Rates (based on API RP 14B) The maa~imum aliowable liquid and gas flow rates are the allowable rates established t'or subsurface safety valves in API Recommended Practice 14B: Liquid - 6.3 gallon per hour Gas - 900 cubic feet per hour Eq,uipment Suggested equipment configuration for the no flow test is shown in the figure below. All equipment must be properly sized to allow for accurate measurement of pressure and flow rate, and in good working order. Pressure gauge and flow meter should carry a recent cali~ration (within the past 6 months). Low pressure gauge; 1-psi divisions Swedge connection to Tree Cap I Flow Meter L_ Hose or flexible line to atmospheric tank (e.g., bucket with water) • • ~ MPU ~37 BOPE Test Corod Deployment Photos by AOGCC Inspector John Crisp August 19, 2008 DM - ~~ • ~~ ('1 ^ S l 6oPc; ~j- i~s~r~~, ,Qp~bN~ ~~ a.~~D V cx,~~a~ BP is working under Sundry approva1308-245; project involves installation of a downhole progressive cavity pump completion with a continuous sucker rod (corod) and surface electric rotating drive head; BOPE approved per 20 AAC 25.288 (Well control requirement for other service operations) Refer to Nabors 3S BOPE test report; Inspection # bopJCr080822122727 for inspection details MPU B-37 tree; BOPE choke line connected to IA; note only a manual valves (no HCR); no way to test valve from wellbore side Corod Deployment BOP; from the top - 2 annular, 1 pipe rams; kill line connected to pump in spool above master valve (no blind rams) ~~ • • BOP Control located on crane truck used to run corod Hyrdraulic pump supplying accumulator pressure Accumulator bottles (4) for BOP control • • Pneumatic backup Remote control panel for BOPE 3 5~~~~ ~~ ~~~~~ ~ ~~~ ~~teviewed By: OIL AND GAS CONSERVATION COMMISSION P.I. Suprv ~~ ~`~3~ BOPE Test Report Comm Contractor/Rig No.: Nabors 3S PTD#: 2070520 DATE: 8/19/2008 Inspector John Crisp i Insp Source Operator: BP EXPLORATION (ALASKA) INC Operator Rep: Menke/Reem Rig Rep: SweaUBjorhus ` Inspector ~... w _ ._, _. _... _a. __. _ Type Operation: WRKOV Rams: Annular: Valves: Inspection No: boplCr080822122727 Type Test: INIT ' TCSt PCCSSUPO: Z50-2000 250-2000 250-2000 '. Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: ~' ~ P/F ~ Visual Alarm Time/Pressure P/F Location Gen.: P Trip Tank NT NT System Pressure 2100 NA Housekeeping: P Pit Level Indicators NT NT ~ Pressure After Closure 2000 NA ~ PTD On Location P Flow Indicator NT NT 200 PSI Attained NA Standing Order Posted P Meth Gas Detector NT NT j Full Pressure Attained 17 sec. NA Well Si~n P H2S Gas Detector NT NT '. Blind Switch Covers: N/A NA Drt. Ri~ P MS Misc NA NA Nitgn. Bottles (av~): N/A NA Hazard Sec. P ACC Misc NA Misc NA { s _~,. _~~_ _.._..__. W..___.._ ._ ,v.~._ ~ .....w. _...._w~~ ...~ .~. . ..,.~,__ _..~. ...._~_. ~_ . . w._..~ W._.k.__~ _~. ~~ ,. _~ ~_ ...._..~ ~ ~ ~ FLOOR SAFTY VALVES. BOP STACK. CHOKE MANIFOLD. { Quantity P/F Quantity Size P/F Quantity P/F , Upper Kelly NA '', Annular Preventer 2 2 9/16" P No. Valves 13 NT ` Lower Kell,y NA : Pipe Rams 1 2 9/16" NA Manual Chokes 1 NT ' Ball Type NA Lower Pipe Rams 0 NA ~ Hydraulic Chokes 1 NT Inside BOP NA ; Blind Rams 0 NA CH Misc NA ~ i FSV Misc NA ' Choke Ln. Valves 2 3 1/8 NT HCR Valves 0 3 1/8 NA Kill Line Valves 2 3 1/8 P Check Valve 0 none NA ~ BOPS Misc 0 none NA ~ } _ _~.. m~__..... .....~a. _~ ~.w .. w.~e___._.~m._._..~ . , _ _ _ _ . . ~~ . ... _ e ~_ T~_~. ....~ ~ ~.~ ~ _ ~~.~ .. ~ .~rm~ . . ~..._.S Test Results ~ Number of Failures: 0 Remarks: Sundry required 3500 high pressure BOP test until stack swapped to Co Rod 2 9/16". CO Rod stack tested to 250-2000 as per Sundry 308-245. The choke manifold had been tested 08-16-2008. I witnessed the kill line valves tested. They had to be swapped to spool above tubing hanger. The choke line was attached to the IA & no answer t~hn~~~ the valv w r tPCtar~ fr m wellbore side. No failures witnessed. Unusual set up for BOP stack due to Rod Completion. I did not think Master Tree valve provided enough protection if Co Rod had to be pulled for any reason. hydraulic blinds would have been a good component if decomplete had been required. The accumulator & controls are located on the Crane Truck that will run the continuous Co Rod. There are 4 accumulator bottles with much more volume than is required by API RP 53. There was one hydraulic pump that suppiies accumulator pressure with a hand pump with a pneumatic control option for back up. remote accumulator control panel located on Rig Floor. Photo's of most of this were taken & will be turned to Supervisor. Sundry #308-245 BOP configuration ~ ~ Maunder, Thomas E {DOA) From: Maunder, Thomas E (DOA) Sent: 7uesday, August 19, 2008 1:27 PM To: 'McLellan, Bryan J' Cc: Rossberg, R Steven; NSU, ADW Drig 3S Wellsite Leader Subject: RE: MPS-37 (207-052) Sundry #308-245 BOP configuration Bryan, Thanks for the update. There is not an issue with moving the kill line. I will place a copy of this message in the file. Tom Maunder, PE AOGCC From: McLellan, Bryan J [mailto:Bryan.McLellan@bp.com] Sent: Tuesday, August 19, 2008 1:02 PM To: Maunder, Thomas E (DOA) Cc: Rossberg, R Steven; NSU, ADW Drlg 3S Wellsite Leader Subject: Sundry #308-245 BOP configuration Page 1 of 1 Tom, As we discussed over the phone, we decided to move the kill line in the Corod Deployment BOP stack up from the Radigan spool on the wellhead to a pump-in sub above the gate valve (master valve). 1 wanted to let you know about the change since this BOP configuration was approved under 20AAC25.288 for "Other" well control equipment. I've attached a drawing showing where the Kilt Line will be hooked up. «Corod BOPE.ZIP» Please feel free to contact me on my cell phone at 907-440-7964 or on Nabors 3S at 907-659-4485. Thank you, Bryan McLellan 8/19/2008 ~ ~ ' Contractor: Nabors Rig No.. 3S DATE: 8/16/20Q8 Rig Rep.: G.Sweatt/R.Bjarht~.s Rig Phor~: 659-4487 Rig Fax: 659- 4486 Operator. BP Qp. P{~one~ 659- 4485 (7p~ Fau: 659-4628 Rep.: J.Menke/D_Rh~ Field/Unit & We!! No.: NfPS~7 PT~ # 207~?52~ Operation: D~lg: Wcxkover: X E~rpior.: Test: Initial: X Weei~ly_ Bi-Weekly Test Pressure: Rams_ 250/350€I Annufar: 250l35t)0 \fahres: 250/3500 T~ST ~~1Tl~l MISC. INSPECTiONS: Tes# Resutf Test Rest~ Location Gen_: P We~ Si~ P Housekeeping: P i3rl_ Ftig P PTD On Location P Hazard Sec. P Standing Order Posted F BOP STAClf. Quantily Size Test Resu~t Annular Preventer 1 '~ 3 5!8 ~Qt3U P Pipe Rams 1 2 718" x~" P Lower Pipe Rams Blind Rams 1 B~nd P Choke Ln. Valves i 3 1f$" SQF~Q F HCR Valves 2 3 1f8" SaQfl F Kil! Line Valves 't 2 1f16" 5t3DD F Check Valve 0 NA MUD SYSTEM: vsual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Test Results FlOOR SAFETY VALVES: Quanti[y Test Result Upper Kelly 1 NT Lower Kelly 1 NT Bat4 Type 1 P [nsicie BO!P 1 P CHOKE MANIFOLD; f2uantity Test Result No. ~J'~Mes 13 P Mar~ua! Chokes 1 P tiydrau~c Chakes 1 P 14GCl~~C[ILATQR SYSTEM: Trme/Pressure Test Result S~tem Press~re 3100 P Pressure ,4fter Ciosure 1700 P 2fl~ psi Attair~ed 30sec P Fulf F'~essure A~air~ed 2 min 45 sec P Bkncf Sv~i#c~ Carvers~ Ail stations P f~Iitgrr_ ~t~tes (avg}. 4~a?2050 Number of Failures: 0 Test Time: 3 Houcs Ccc~mmv~t~nents tested ALL Repair or replacemerrt of eq~ip~~rtt v~ip' be made w~thin ciays. hlatify the North Slope Inspector 659-36t}Z, fo~v rnr~ v~te~- ccrrt~neafion tc~ ~pee~ise€ at~ i .~.. ._._ w .. Remarks: Tested w/ 3 112 test iai~rt_ Aaau~st hancter ancci T{~V'C. This test was done after~ ttte nitroaen foam cleanout was done with a tree on itue +u~ell_ 2~ H~UR N~TICE GNEN ~s x ~ua _ Date f}$!t 5ff18 T~rrte f 8:30 est start 21:~t3 Finish BOP Test (for rigs) BFL 11114J07 By Chuck Sheve Witr~ess R.Siorhus / D.Rhodes Nabors 3S BOP Test MPS - 37 8-16-08.x1s STATE OF ALASKA 11/14/07 OIL AND GAS CONSERVATION COMMISSI~N BoFE Test Report Submit to: _ Contractor: Nabors Rig No.: 3S DATE; 8/11/2008 Rig Rep.: J.Greco/E.Potter Rig Phone: 659-4487 Rig Fa~c: 659- 4486 Operator: BP Op. Phane: 659- 4485r C}p. Fax: 659-4628 Rep.: J.Menke/D_Rhodes Field/Unit & Well No.: MPS-37 PTD ~ 2070520 Opera6on: Drlg: Worlcover: X EE~lor.: Test: Initial: X Weekly: Bi-Weekly Test Pressure: Rams: 250/3500 Annular. 25Q/3500 Vahres: 250/3500 TEST DATA MISC. INSPECTlONS: Test Result Test Result Location Gen.: P WeN 5ign P Housekeeping: P Dr1. Rig P PTD On Locafion P kiazasd Sec_ P Standing Order Posted P BOP STACK: Quantity Size Test Rese~it Annular Preventer 1 13 5/8 5000 P Pipe Rams 1 2 7J8" x 5" P Lower Pipe Rams Blind Rams 1 B1'rnd P Choke Ln. Valves 1 3 1!8" 5000 P HCR Valves 2 3 1f8" 5000 P Kill Line Valves 1 2 9/'!6" 5000 P Check Valve 0 NA Lower Kelly 1 NT Batti 7ype 1 P Inside BOP 1 P FLOOR SAFETY VALVES: Quanttityy Test Result Upper Kelly 1 NT CHOKE MANIFOLD: Quantity Test Result No. VaMes 13 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure System Pressure 3100 Pressure After Ctosure 1700 AAUQ SYSTEM: V'~suai Test Alarm Test 200 ps~ A#tamed 26sec Trip Tank P P Fuli Pressure Attained 1 min 55 sec Pit Level Indicators P P Bknd Switch Covers: All stations Flow Indicator P P Nitgn. Battles (avg): 4@2050 Meth Gas Detector P P H2S Gas Detector P P Tes# Resutts Test Result P P P P P Number of Failures: 0 Test Time: Hours Comaonents tested ALL Repair or replacemerrt of equipment will be made w~thin 3.5 days_ Notify the North Slope Inspector 659-3607, follow with written confirmation to Supenriser at: ;„ ~.. Remarks: Tested w/ 3 1/2 test ioirrt 24 HOUR NOTICE GlVEN YES X l~l~ Waived By Chuck Sheve Date Q8I09/08 Time 17:00 est start 18:30 Finish BOP Test (for rigs) BFL 11/14/07 Wi~tess E.Potter / D.Rhodes Nabors 3S BOP Test MPS - 37 8-11-08.x1s ~ € ~-_.•~ ,---~~ s,-~ ~. ~. ~ ~ ~ ~~~'~~~ ~ " ~~~ ~~~~ ~ ~.°~ ~; . ~ ~ ~ ~~ ~-~ ~ ~.~~ r t~ '~~ ~ ~~ ~~ ~ ALASSA OIL A1~TD GA,S COI~TSERQATI011T CO1~II-IIS5IOr1T David Reem Englneering Team Leader BP E~loration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 ~ SARAH PALIN, GOVERNOR 333 W. 7thAVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Re: Milne Point Unit, Ugnu Undefined Oil Pool, MPS-37 Sundry Number: 308-245 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, conta.ct the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, withuz 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for xehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the ne~ worlflng day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair '~~. DATED this Z~ day of July, 2008 Encl. ~v,~ ~S~ , . . STATE OF ALASKA ~y~ ~ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of RequeSt: ^ Abandon ^ Suspend ^ Operation Shutdown ~ erforate ^ Time Extensio-~j~~~=~~;~;`:~~~ ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ~ Re-Enter Suspended Weli ^ Change Approved Program ~ Pull Tubing,~ ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. i~ Development ^ Exploratory 207-052 ' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23355-00-00 ~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: MPS-37 ~ Spacing Exception Required? ^ Yes ~ No 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): , ADL 380110 ~ 71.88 ~ Milne Point Unit / Ugnu 't2~ PRESENT 1IVELL CONQITIQN SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 4814 ' 4385 ~ 4380 - 3978 ~ None None Casin Len th Size MD ND Burst Colla se Structural Cond ctor 115' 20" 115' 115' 1490 470 SurFace 3822' 9-5/8" 3857' 3487' S750 3090 Intermediate Pr duction 4761' 7" 4794' 4366' 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None 3-1/2", 92# (Kill String) L-80 2530' Packers and SSSV Type: None Packers and SSSV MD (ft): 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal ~ BOP Sketch ^ Detailed Operations Program ^ Exploratory ~ Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: August 1, 2008 ~ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bryan McLellan, 564-5516 Printed Name vid Reem Title Engineering Team Leader Prepared By Name/Number: Signature ~,y~~. Phone 564-5743 Date ~ 9~ Sondra Stewman, 564-4750 Commission Use Onl Sundry Number. ~_~~ Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ~OP Test ^ Mechanical Integrity Test ^ ocation Clearance Oth r: ~ ~ ~ ~° ~,~ ~~ e ?~`~1~~ ~S ~ ~~~ ~5~~~~~C~ ~S` G C~~ ~S~ ~ ~4 ~a~ C ~ - ~ L3 ~ ~ ~ ~ + ~:.~5 r,E~~ - E ,. - ~ v , c~ ~EC~ ~~LL b c~> Subsequent Form Required: i ~ APPROVED BY / Z~j ~ ~ ~ A roved B. COMMISSIONER THE COMMISSION Date ~ ~~ Form 10-403 Revised 06/2006 ORIGINAL ~~~~~~`~~z0°~ ~~~~~~~~~ ~ ~ , ~'~J° ~ 0 2Q08 •V~ 71k.;:Y~3.3YC. L F~ WS" ~~v".~'.r w.WS.J~7Jr ~Q9i3~E i~~' a`~?Jt~ Submit In Duplicate ~a , .,~. n o . RE: Meeting to discuss MP ~7 Maunder, Thomas E (DOA) From: McLellan, Bryan J [Bryan.McLellan@bp.com] Sent: Monday, July 14, 2008 5:28 PM To: Engel, Harry R; Maunder, Thomas E(DOA) Subject: RE: Meeting to discuss MPU-37 Attachments: MPS-37 Sundry rev1.pdf ~ Page 1 of 1 Tom, As I mentioned on the phone, I'm sending you a copy of the Sundry application. Note that the Scope of work document already has been changed since the original one that 1 sent to you. Please consider this to be the up to date Scope of work. ~ «MPS-37 Sundry rev1.pdf» We wif; need commission approval for the proposed secondary Well Control equipment for deploying continuous sucker rod (Corod) under section 20 AAC 25.288. This will be the main subject of the below referenced meeting. Please feel free to cal~ with any questions. Sincerely, Bryan McLellan BP Exploration, Alaska 907-564-5516 From: Engel, Harry R Sent: Monday, ]uly 14, 2008 5:07 PM To: Maunder, Thomas E (DOA) Cc: McLellan, Bryan 7; Engel, Harry R Subject: Meeting to discuss MPU-37 Hi Tom- Bryan McLellan and I would like to meet with you to go over the Sundry for MPU S-37. This is the heavy oil completion at Milne Point. How about this Wed at 10 am, your office? I expect we need at least ~ hour. Options... any time Wed morning or any time Thursday afternoon. Thanks, Harold R. Engel (Harry) Engineering Team Leader Integrity Management, Alaska Drilling & Wells 907-564-4194 office 907-564-5510 fax 7/17/2008 ~ ~ ~ ~ ,_ ~..- ~~ ~~ ` :~ ~ ~~~ ..: ~~'~ . ~~~~ '': ~~ ~ _ ~lPS-37 In~tial Per#oration a~d comp~etior~ ~ ~ S~ope flf Work: Capitat ~cornp~etion - Puii 3-1/2" ~.-8fl kil~ strir~g, ~r~r#ora#e #he Ugnu 42~t~' - 427~' md, cl~an up sand wit~ #~am ciean Qut, n,~n 3-1l2" L-8U Progressing Caviiy (PCj Pump completion wit~ continuc~us suaker rod and Electric r~tating drive head. M~1SF'; 7345 psi Wei1 Type: l~gnu Prvducer Estimated Sta~i ~aie: Aug~st 1 st, 2008 Production E~gineer; Bill Ma#hews lnterventifln Engineer: Bryan McLelian Pr~~osed ~rocedure 1, MIRl1 rig ~labs~rs 3S. Circulate c~ut freeze pro#ection #~uid ~r~d circulate w~ll tfl cie~n ki~l wsight filuiti. ~I[? tree. N~ and tesi BOPE to 35D{l psi, 2. Lay down tul~ing hanger. FiIH ~nrith tubing to PBT~ at ~-438fl' md and circulate t~ut 9,5 pPg l~rin~ wi#h kill weight iluid. PQUH jnri~h 3-9I2" workstring. 3. R1H ~+3i~ perf guns on tu~ing. Run E-line f~r depti~ correction. Perft~rate the Ugnu tv18U Lower sand #rom 426q' - 4275' md. Pflt3H with pe~fi gu~s, 4. R1H with 3-112" tubing u+ork string to ~428~'. Land tubing in hanger a~d RI~[~S. 5. )nstall TWC and pressure t~st. 6. N~ ~OP stack. ~!U tree, 7. Rlg up Niirogen pumping line tc, IA casing valve. ~.in~ up to take re#urns frorn ti~e si~le outlei on #he tree #o the portat~8e test separator, 8. Begin purr~ping nitrifie~3 foam dc~wn inner annuius, taking returns up th~e tubing, out #t~ a cht~ke and tt~ a portable test separatar. 9, ~~on#inue foaming opera#ion un#i~ sand concentration reaches a level cleerr~ed manageabls by the J'C Pump. Displa~e fflam with k~ll weight iluid. 10, Set TWG, N!] tre2. 11. NU and tesf BOP's. 12. Pull #ubing wt~rk s#ring out of t~e hole. 13, F~un 3-i12" ~.3# L-80 cc~mpleiion tubing with hea# trac~ and gauge ~ire. There will be n~ prflduct~on packer on this PCP cornpletion. 1A. ~e# and test TWC, NI} BflP sia~k. NiJ 3-1/8" 300~ psi pr~duciion flt~w T and 3-118" 5{~{~ psi master vaive. 15. RU lubricator and pull T1NC, NU Continuous ~ucker rod ~Corod) B~?P stack ~see Carc~sci BC?P schematicj. Pressure tes# Corod BOP equipment ta 20U0 psi. ~fi. RU Corod in~ector, Run PC Pump rotor on the end of Corod, Space out and land tt~e Pc~lished r~d in the producii~an ilow T and close r~ms on po~ist~e~l rod. 17, IVD BOP stack and master valve. Nl1 rotating drive head {ses CH{)F'S productic~n we4lhead schematic}. 18. Rul! totor out of the st~tot vvi#hou# pullirtg polish$d rt~d flut c~f stuffir~g bc~x. Freeze protect #ubing and annulus. L.and rotor back in siator. ~ ~ U 19. R~MQ Nabors 3S. • ~ ~ !~ . !,. ' ?" ` s~ s ~~. . t' -~~~c~+ ~ k ,.'~ ~~~ ~ { j • MPS-37 Initi~I,Perforation and completion Scope of Work: Capit completion - Pull 3-1/2" L-80 kill string, perforate the Ugnu 4260' - 4275' md, clean up sand with foa lean out, run 3-1/2" L-80 Progressing Cavity (PC) Pump completion with continuous sucker rod an Electric rotating drive head. MASP: 1345 psi Well Type: Ugnu Producer Estimated Start Date: August 1 s 2008 ~~~~~~'~~~~ Production Engineer: Bill Mathew Intervention Engineer: Bryan McLel n ~~ `~ ~ ` ~ % ! Proaosed Procedure 1. MIRU rig Nabors 3S. Circulate out freez rotection fluid and circulate well to clean kill weight fluid. ND tree. NU and test BOPE to 3500 psi. P stack to include secondary mud cross for foaming operations (see BOP schematic). 2. Lay down tubing hanger. RIH to PBTD at -43 0' md and circulate out 9.5 ppg brine with kill weight fluid. POOH with 3-1/2" workstring. 3. RIH with perf guns on workstring. Run E-line for pth correction. Perforate the Ugnu MSO Lower sand from 4260' - 4275' md. POOH with perf guns. 4. RIH with 3-1/2" workstring to ~4280'. 5. Install stripping head on top of BOP stack. Rig up nitro en unit and begin pumping nitrogen foam down the work string, taking returns out the secondary m d cross to an external choke and then to the portable test separator. Double manual valves will be nged up to the mud cross. The line from these double valves to the external choke skid will consist o" hardline with hammer unions. 6. Continue foaming operation until sand concentration reaches level deemed manageable by the PC Pump. Displace foam with kill weight fluid. 7. Pull workstring out of the hole. 8. Run 3-1/2" 9.3# L-80 completion tubing with heat trace and gauge 're. There will be no production packer on this PCP completion. 9. Set and test TWC. ND BOP stack. NU 3-1/8" 3000 psi production flo and 3-1/8" 5000 psi master valve. 10. RU lubricator and pull TWC. NU Continuous sucker rod (Corod) BOP sta (see Corod BOP schematic). Pressure test BOP equipment to 2000 psi. 11. RU Corod injector. Run PC Pump rotor on the end of Corod. Space out and nd the Polished rod in the production flow T and close rams on polished rod. '~ 12. ND BOP stack and master valve. NU rotating drive head (see CHOPS production wellhead schematic). 13. Pull rotor out of the stator without pulling polished rod out of stuffing box. Freeze protect tubing and annulus. Land rotor back in stator. 14. RDMO Nabors 3S. ~ ~ Tree: Cameron 3 1/8"- 5M Wellhead: 11" x 3 1/2" FMC Gen V Tubing Hanger, TC-II t&b threads, 3" CIW `H' BPV profile 20" welded/insulated, 106` 91.1 ppf, H-40 9-5/8" 40#/ft., L-80 BTC 3857' KOP @ 500' Max Hole Angle = 34 deg. f/ 2700' to 3000' Hole angle through perfs. = xx deg. DLS = 4.7 deg/100' @ 1284' 3 1/2" 9.3 ppf, L-80, IBT-M Tubing (drift ID = 2.867", cap. = 0.0087 bpf) 7" 26#/ft., L-80, BTC, production Csg (drift ID = 6.151", cap. = 0.0383 bpf) Stimulation Summarv Perforation Summarv rcer. ~og ~i~i~ xxw xxx Size SPF Interval TVD "XXXXX Je t Charaes la~ 60 dea. ohasina" ~ Orig. DF Elev. = 71.88` (D-14) Orig. GL Elev. = 38.10' (D-14) DF to Csg Spool = 32.61 `(D-14) MPS-37 31/2" Muleshoe 7" ES Cementer 2530` I 3372` I 7" Baffle Adapter (PBTD) 4380` 7" float collar 4442` 7" float shoe 4794` DATE REV. BY COMMENTS 6/29/07 Hulme Drill and csg set - D-14 MILNE POINT UNIT WELL MPS-37 API NO. 50-029-233550-00 BP EXPLORATION (AK~ ___ _ ~roposed MPS-37 CI-~PS Tree: Cameron 3 1/8" - 5M Orig. DF Elev. = 71.88` (D-14) Wellhead: 11" x 3 1/2" FMC Gen V Orig. GL Elev. = 38.10' (D-14) Tubing Hanger, TC-II t&b threads, DF to Csg Spool = 32.61` (D-14) 3" CIW `H' BPV profile 20" welded/insulated, 106` 91.1 ppf, H-40 9-5/8" 40#/ft., L-80 BTC 3857` KOP ~ 500` Max Hole Angle = 34 deg. f/ 2700' to 3000' Hole angle through perts. = xx deg. DLS = 4.7 deg/100' @ 1284' 3 1/2" 9.3 ppf, L-80, EUE 8rd Tubing (drift ID = 2.867", cap. = 0.0087 bp~ 7" 26#/ft., L-80, BTC, production Csg (drift ID = 6.151°, cap. = 0.0383 bp~ Stimulation SummarX 1" OD round Corod 3.5" 9.3# EUE 8rd tbg with Torque rings ' Pertoration Summarv Ref. Loa ##/##f## xxx/xxx Size SPF Interval TVD 5" 4.5" $ 5 4260-4275' 4260-4275' "X~CXX Jet Charges @ 60 deg. phasing" 7" ES Cementer 3372` Heat Trace Cable 3500` Tbg Drain Sub, 432Q psi 3925` Corod Shear Tool, 30K # 3939` SLB TEC Gauge carrier 4162` HES X-Nipple (2.813" ID) 4217` I WFD PCP 4257` Slotted Tag Bar 4280` 7" Baffle Adapter (PBTD) 4380` ~ 7" float collar 4442 ~II 7" float shoe 4~94~ DATE I REV. BY I COMMENTS 6/29/07 Hulme Drill and csg set - D-14 6/17/08 McLellan Proposed CHOPS completion MILNE POINT UNIT WELL MPS-37 API NO. 50-029-233550-00 BP EXPLORATION (AK~ ' Nabors 3S ' . ~ BOPE for Foam Clean Out ~ Well # MPS-37 4' 6 1/8" 1' S I /4" I' 10" 2~ ~~~ 1' S 1 /4" Strippin~ Head Test spool = 2' 3" Annular Blind Rams Test Separator Pipe Rams Lock Down Screw to Floor Ground Level to Ri~ Floor Kill Line ~ ~ ~, . ,• ~ • BOPE for Corod Depioyment Corod safery Pump-in sub w/ 1502 hammer union 2 annula Top Corod Safety 3' above Rig floor Rig Floor 23.8' above GL 3-1/2" lubricator secuoas with OTIS Quick connects 3-1/2" tree cap flauged to top of Hydril (need ~c/o 2-4/16 SM flange x 3-1/2" OT'IS QC) Too of Annulars 14' above GL : ram 11.4' above GL Pipe ran X/O 3-1/8" SK x 2-' 3-1/8" 5 X/O 3-1/8" 3K x 3- Radigan Choke Line t .:tl" SOOOM ~::; ~ with ~c/o (3-1/8" SK x 2-9/16" SK) 9.48' above GL ooltop 6.55'above GL Kill line spool 3.80'above GL ~ '' .• ~ ~ ~ CHOPS Production Wellhead and Tree Electric Rotating Drive Head ~ • 3-1 /8", 3000 psi Flange Production Flow T ~ 3-1 /8", 3000 psi Heat Trace Cable ~ & Penatrator 0 ~ Rod Rams ~~ i-wire Cable ~ Tubing Spool 11'; 5000 psi 2-1 /16", 5000 psi RE: Meeting to discuss MP ~ Maunder, Thomas E (DOA) From; McLellan, Bryan J [Bryan.McLellan@bp.com] Sent: Fri~tay, July 25, 2008 4:06 PM To: Maunder, Thomas ~ (DOA) Cc: Engel, Harry R; Mathews, William L Subject: R~: Meeting to discuss MPS-37 (207-052) Tom, I apologize for the delayed response to your request. • Page 1 of 3 On item number 1, regarding more_detail around the lack of a conventional surface_safety. valve .(SSV) in the Progressive Cavity Pu__mp (PCP) completion on MPS-37: - _ _ a) The PCP is rod driven from surface, so there is a polished rod running through the wellhead. The presence of the rod prevents ciosing a valve on the tubing, so a conventional SSV design would not work_ b) There will be a SSV on the wing valve, flanged to the outside of a manual wing valve on the side outlet from the Production flow Tee. This SSV wiil be set up with a remote hydraulic panel. It will be manually operated and will not have a low pressure pilot on the flowline. If the vaive were to shut in automatically with the pump still operating, the pump could potentially overpressure the seals on the rotating drive head. c) There will be a SSV on the IA casing valve, flanged outside of a manual casing valve. This SSV will also be set up with a manual, remote hydraulic panel. The small amount of casing gas will flow from the IA and be commingled with the production stream from the tubing. e) The density and viscosity of the oil suggest the the well will not be capable of unassisted flow to surface, however with this being the first completion of this type, we can not conclusively state that it won't flow. By shutting down power to the PCP pump, flow should stop. d) There will be 24 hour operator coverage on this pilot project. The operator will be prepared to remotely kill power to the drive head and shut the SSV's. On item_number 2, regarding approval for"Well Control Requirements for other Service Operatio_ns" 20_AAC 25.288. _ Deploying or pulling sucker rod or continuous sucker rod (Corod) is not addressed in the current regulations with respect to secondary well control equipment. We have included a Corod BOP schematic with the Sundry and discussed with you the plans for maintaining well control. We request approval for Well Control equipment under the "Other Service Operations" 20 AAC 25.288 in the regulations. Please ;~t me know if you require additional information on either of these topics. Thank you, Bryan McLellan BP Expioration 907-564-5516 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, July 17, 2008 3:42 PM To: McLe(lan, Bryan J Cc: Engel, Harry R ~i2si2aos RE: Meeting to discuss MP i i Page 2 of 3 Subject: RE: Meeting to discuss MPS-37 (207-052) Bryan and Harry, Thanks for meeting with me today regarding the plans for the Ugnu completion in MPS-37. A very interesting and pioneering operational plan. This will introduce new technology to the NS. I appreciate the thorough brie~ng regarding the plans. There was one item for sure that came up in the discussion and possible another. 1. You indicated that it was not planned to employ a surface safety valve. Would you please provide further detail on this? 2. We discussed the non-conventional nature of some of the BOP equipment and that approval under "other" might apply. Can you provide a request with regard to the need for "other" approval? Thanks in advance, Tom Maunder, PE AOGCC From: McLellan, Bryan J [mailto:Bryan.McLellan@bp.comJ Sent: Monday, July 14, 2008 5:28 PM To: Engel, Harry R; Maunder, Thomas E(DOA) Subject: RE: Meeting to discuss MPU-37 Tom, As I mentioned on the phone, I'm sending you a copy of the Sundry appfication. Note that the Scope of work document already has been changed since the original one that I sent to you. Please consider this to be the up to date Scope of work. «MPS-37 Sundry rev1.pdh> We will need commission approval for the proposed secondary Weli Control equipment for deploying continuous sucker rod (Corod) under section 20 AAC 25.288. This will be the main subject of the below referenced meeting. Please feet free to call with any questions. Sincerely, Bryan McLellan BP Exploration, Alaska 907-564-5516 From: Er~gel, Harry R Seat: Monday, 3uly i4, 200$ S:Q7 PM To: Maunder, Thomas E (DOA) Ce: McLellan, Bryan J; Engel, Harry R Subject: Meeting to discuss MPU-37 Hi Tom- Bryan McLellan and I would like to meet with yau to go over the Sundry for MPU S-37. This is the heavy al completion at Milne Point. How about this Wed at 1 Q am, your office? I expect we need at least 1 hour. Options... any time Wed morning or any time Thursday afternoon. Thanks, Harold R, Enge! (Harry) 7/28/2008 ~ To: State of Alaska WELL LOG TRANSMITTAL Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evalua.tion Logs: MPS-37 December 20, 2007 AK-MW-5043799 MPS-37: Digital Log Images: 50-029-233550000 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. `°'t~. ~~ ,~, , ~~~~~` r; ~~~=~r n'~ ~ ?~~i D~a~e: '~1;.+~1 ""' 3. ,.;i -.~'~ '1,f9,' + '.t : ~ is~s$' '~ =k:~'~;~..>. +~:i'•^- BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: y ~ ~o~-_~ a r s~b ~ ° ~. ~ WELL LOG TRANSMITTAL To: State of Alaska December 18, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: MPS-37 AK-MW-504379 1 LDWG formatted CD rom with verification listing. API#: 50-029-233 55-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 , ~ ~, ~ j ~; ~--° ~ ~,, ~ a ~,r ~ ~ ~~{ ~ ~ ~~''~'8'- y ~ ?;l~?a 1~ Date: ~~ `~` ~"`' Signed: _ .~.~. ;; ~., _ ~, ,,. _ ~~~;~ _~ ' cJ::~ ~"~ ~0~, ~a ~ ( 5 11 /15/07 i ~..I .~~.-..,~ ......~..,..~~.,.~~ ~~~..~~~ ~,, ~~~v~.~~~v r1~~~ RC 1 NRIrIP1.V. VIYC l~V/'i ~ra~,n i ~: BP Exploration (Alaska) Inc. ~ ~- ~ ~ a ~ ~ r - ~ ~- Petrotechnical Data Center LR2-1 ~ ~ # ~ {t.-5- ~ ~ ~~"m °" 900 E. Benson Blvd. Anchorage, Alaska 99508 ~ , ~~~~~~~ g ~ 0..~~s~ ~j~ C~ ! Date Delivered: ;,~p~ 4xqq~~~ a6t:r? i ?B;.tK~~d~9~~ ~ >>;i~aikq . ;1,r:'y'~r 1 6°1:'; ~~ill~~:~~~a~~~~ NO. 4498 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite aoo Alaska Oil 8 Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 700 Anchorage, AK 99501 Field: P.Bay, Pt. Mac. Milne Pt. Well Jnh dt 1 nn (lncrrinfinn n~~~ ni ~..~... rn MPS-37 11594513 OH LDWG EDIT ~t /a 06/26107 6 2 1 J-25A 11767130 MCNL t:t 6p 06/18/07 1 1 OWDW-SW 11483588 RST v Z„~ L~(j -'3 ~ 11/17/06 1 1 OWDW-NW 11626127 RST (~~ 10/09/07 1 7 OWDW-SE 11225967 RST ,V G~.- l 04119/06 1 1 M-12A 11216184 MCNL (~ -. ~ 'a 04104107 1 1 P1-09 11773114 RST ~ G ~j `' 04/24/07 1 1 OWDW-SE 11855823 RST ~ ~ pZ~ _ •'~ ~ 10/28/07 1 1 C~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth /I Received by • ~~ ~~ ~~ n~ . Date 10-22-2007 Transmittal Number:92911 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC ar ~~a_ana~ SW Name Date Contractor Log Run Top De th Bottom De th Lo T e MPS-37 10-18-2007 OMNI HALF SCALE PHOTOGRAPHY CD ROM / /~ ~ ~'. i ~~--~~ ~ ~e s~~ c~ Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center ~`~~~~y,~~ J A ~~.' ~~: 3 ~, ~`~ ~~~s $ G t3 i~Ul~~ ,~:~s~~ ~i~ ~ .~~s °<>~ ~ _ .,~~~ ~~~;~;~, ,~r~~f~r~ ~ Attn: Kristin Dirks DNR Christine Mahnken AOGCC ~ ~~ ~ 'r d i ~6/iJ ~ L> ~e~/ b ~ ~~Q ! V~a ~1v ~ ~ ( 9 ~JV ~ ! / ~+~"7_ ~ U l~v"°~~~'_ 1 v ~ t t /^ '~ l~ ~ j't Q..(1 P(~ T'vi.! fit '' o r ~-- (~tJ )~~ ~ l ~~~ 2~~ 1~ 1i(. ~'/C~~ .~- ~ C/ P trotechnical Data Center LR2-1 e 900 E. Benson Blvd. PO Box 196612 `~_ / Anchorage, AK 99519-6612 /;'~"}C --~ 09/27/07 ~ ~~~~~~~~~~ NO. 4437 Alaska Data 8 Consulting Servlces Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil 8~ Gas Cons Comm Anchorage, AK 99503-2538 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Fieid: Prudhoe Bay Wall .Inh !t 1 nn flasrrinfinn 1'1a}a RI Cnlnr CI~ 15-29A 11686783 SCMT d - 09/05/07 1 05-25B 11630496 SCMT _< 08/30/07 1 02-33A 11813082 SCMT 08/31/07 1 15-28A 11686782 SCMT 09/04/07 1 N-27 11824345 SCMT - ~ 09/12/07 1 05-22A 11813086 SCMT 09/18/07 1 S-400A 17855508 USIT - 09/18/07 1 E-27A 11676963 USIT (CEMENT) 1 - 09/18/07 1 E-27A 11676963 USIT (CORROSION) - 09/18/07 1 MPG-07 11594520 USIT S - ' 08/29/07 1 MPS-37 N/A SCMT - 09/08/07 1 YLtA~t AI:KNUWLtUCit Ktl:t1Y 1 I3T SIti1VING ANU Kt 1 UfiNING UNt GOYY bAGM 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Bivd. ;(,~ ~ ~ i-- ~ 4 '`~ ~ ~ ~i ~; Anchorage, Alaska 99508 ~~ '~ ~... , `.~ ! ~ , ~~ ~' ~{ Date Delivered: - - ~`~ ,, - ~ Alaska Data & Consulting Serv~ es 2525 Gambell Street, Suite 4 0 Anchorage, AK 99503-283 ~ ATTN: Beth ~ ~ _ ..._._ _~. ~~.,_, ~ ° ~.____ Received b ~ j~ , .~,~~~a~ u ~kE +~. ~ ~ ;~ ;.,~_~filll~lS~14~E4 .,,, ., . '~.i 1 t ;s lt.~! c;cs,t.~. ~ ~ Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Sent: To: Cc: Hubble, Terrie L (Terrie.Hubble@bp.com] Tuesday, September 25, 2007 1:41 PM Saltmarsh, Arthur C (DOA) Stewman, Sondra D; Eddy, Andrea (SAIC); Mathews, Wlliam L; Hanson, Paul ~~J`~ .~~,~-~_ Subject: MPS-37 / PTD # 207-052 H i Art, Per our phane conversation earlier today regarding the status of this well. The 10-407 was submitted upon completion of drilling operations, but prior to initial perfing. I spoke with the Production Engineer for that well (Bill Mathews, x5476) and he tells me that BP wi1! in fact be perf'ing the well, but not until next spring / summer (2008). Therefore, based upon your recommendation, it does seem reasonable to change the status of this well from Oil Producer to Suspended. Pfease make this change, as we w'rl! on our copies. And, of course, we will submit a revision after the well is initially perfed. Thank you, Terrie Hubble 9l26/2007 ! ~~,`~ ~~ ~~~~iv~i~ STATE OF ALASKA AL4SKA OIL AND GAS CONSERVATION COMMISSION `~~,_~;; ~? 7 200~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~/~ /~~ ~~ai~~,Na Jii ~ Gas Cans. Gammission AN~ / !/l(J~/ ttnrhnrnnu 1 a. Well Status: ~ Oil ^ Gas ^ Plugged ^ Abandoned • Suspended zoAnc zs.,os zoa>c zs., ~o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions O 1 b. Well Class: ~ Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Ab ~ 6/29/2007 ~/ ~ 12. Permit to Drill Number 207-052 ~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 6! /2007 -~'d~ 13. API Number 50-029-23355-00-00 ~ 4a. Location of Well (Governmental Section): Surface: ~ ' ' 7. Date T.D. Reached 6/24/2007~ 14. Well Name and Number: MPS-37 - FSL, 460 FEL, SEC. 12, T12N, R10E, UM 3239 Top of Productive Horizon: 2204' FSL, 646' FWL, SEC. 7, T12N, R11 E, UM (As Planned) 8• KB (ft above MSL): 71.88 Ground (ft MSL): 38.1 15. Field / Pool(s): Milne Point Unit ! Ugnu , Total Depth: 2026' FSL, 821' FWL, SEC. 7, T12N, R11 E, UM ' 9. Plug Back Depth (MD+~/D) 4380 3978 , 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 565551 ` y- 5999905 ' Zone- ASP4 10. Total Depth (MD+~/p) 4814 ' 4385 -_ 16. Property Designation: AD~ 380110 ~ TPI: x- 566666 y- 5998879 Zone- ASP4 Total Depth: x- 566843 y- 5998703 Zone- ASP4 11. SSSV DeN A(MD+~/D) 17. Land Use Permit: 18. Directional Survey ~ Yes ^ No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore ~1~A ft MSL 20. Thickness of Permafrost (TVD): 09 pprox.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): ~. ZG •~~ MWD, GR, RES, IFR/CASANDRA, DEN/NEU w/ACAL, SONIC (BAl), GYRO ZZ. CASING, LINER AND CEMENTING RECORD CASING SETTING DERTH MD SETTING DEPTH ND HOLE AMOUNT VVT. PER FT. ' GRADE ' TOP BOTfOM TOP BOTTOM SIZE CEMENTING RECORd PUI.IED - 20" 92# H-40 Surface 115' Surface 115' 48" 260 sx Arctic Set A rox. 9-5/8" 40# L-80 35' 3857' 35' 3486' 12-1/4" 467 sx AS Lite 360 sx AS1 7" 26# L-80 33' 4794' 33' 4366' 8-1/2" 296 sx Class'G' 23. Open to production or inject ion? ^ Yes ~ No . 24, ` TuaiNC RecoRa If Yes, list each interval open (MD+TyD of Top & Bottom; Perforation Size and Number): Size ~EPTH SET MD PACKER SET MD None ` 3-1 /2", 9.2#, L-80 2530' MD ND MD ND ZrJ. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT Hc KIND OF MATERIAL USED Freeze Protected with 85 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test: Hours Tested: PRO~ucTior, FoR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: C,n~cu~a,Teo 24-HouR RnTei OIL-BBL: GAS-MCF: , WATER-BBL: OIL GRAVITY-API ~CORR~: 27. CORE DATA Conventional Core(s) Acquired? ~ Yes ^ No Sidewal l Core s Ac uired? ~ Yes ^ No If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. S~F~, SEP 2 81007 ~ o m/ See Attached - Geological and Operational Summary ,~~ Form 10-407 Revised 02/2007 TINUED ON REVERSE SIDE ° ~.~k ~~`, %~~ ~ 28. GEOLOGIC MARKERS ~LIST ALL FORMATIONS AN KERS ENCOUNTERED~: 29. FORMATION TESTS ' NAME MD TVD Well Tested? ^ Yes ~ No Permafrost Top SurfaCe Surface - ~f yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base 2040' 1914' ~ detailed test information per 20 AAC 25.071. TUZC 3904' 3531' UGNU MA 4125' 3739' M B 1 4147' 3759' SBF2 - Top NA 4377' 3975' SBF1 - Top NB 4403' 3999' Top NC 4435' 4029' Top NE 4447' 4040' Top NF 4502' 4092' TSBD - Top OA 4538' 4126' Base OA/TSBC 4570' 4156' TSBB - Top OB 4597' 4181' SBA5 - Base OB 4624' 4206' Formation at Total Depth (Name): Schrader Bluff 4377' 3975' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys, Geological and Operational Summary and a Leak-Off Test Summa . 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondra tewman .`_ Title Technical Assistant Date (~(~ ~ MPS-37 207-052 Prepared By NameMumber. Sondrd Stewman, 564-4750 Well Number Permit No. / A f'OV21 NO. Dnlling Engineer: paUl HBnSOn, 564-4195 INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 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). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITenn 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). Irenn 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITeM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original ONy , , ~ ~ S:\SS Dnlling\Well Reskt - Completed Nklls\Ntilne Pdnt\MP S-Pad\MPS-37 Coho #1\1Losts and NkX Plan\Completion\COHOTest COMPLETE.CNV 07/3Q~07 C~ 04~.12 PM Page t of " MPS-37 COHO-01 Orig.KBElev.=7T.9' Wellhead~ 11 SKFMC Tree: Cameron 31/8" SK ~ r ~~ ~, ~ '~ ~ i~~ ~~ ~ ~~~~ " ~ ~~ ~~ ~~~~'~?~~~4 ~ (~ ~ '~ ~ ~ ~''_ 20 . 92#, H-40. Welded - ~ ~ ~ ~;_ Insulated Conductor at - : -80' MD ~ t ~) ` Diesel Freeze Protect-2200' MD KOP @ 500' ~ ~~~~~ - ~(~ 85 bbl Max HdeAngle= 30 deg. -,~- "~ f/1484' - 3369' MD 34 bbl 92 ppg Brine ~ 3112", 92#, L-80, IBT-M Tubing (outside DV Collar) ~ ~, at -2500' MD (Ciculation Stnng) ~ $~ ~ ~ (" " ' 7" DVCoNarlTOC-3381' MD ~ ~ ~ , , ~ 9S/8", 40#/ft., L-80 BTC -3856' MD ;~ ~ ~ .,:: a 9.4 ppg Brine Cement ~ -+~ _ ~ ~~ E ~ r } F~ 7" 26#/ft., LBO, BTGM Casing `~- ~ ~ ' (DriftID=6 151" ca =0 0383b ~ ~ ~~- ~ leaend . , p. p . -`~' Diesel ~ , ~ ;; Cement ~ i'~; ~ ~ti a7i 9.4ppgBnne ~ ~ ~?i " ° ~~~ ~ ii i ~ ~ s =" .:' i~, p` ' ~ ~, ~,- ~ '~ ~ ~ I ~~ ~ ~ ~ ~ ~ " : '~ ~ ~ ~ r , i i , ~ ~ ~ '~.'. ~~ ~ 4~ I, .. a .... i P~Td 4~9 . ~ ~ " ~ BaffleAdaptor 7 ~ ~~ ~ ~~ ,, x 7" Float Collar 4443' MD ~ ~ it'~) ~ ,~:.- o~~s c ~ ~ ~ ~ ~ ~ ~ ~ T ~~ ~~ "~' ~~ #` 7" Float Shoe 4793' MD DnTE REV. sv COMMENTS MILNE POINT UNIT 04/11/07 JGR PlannedCompletbn MPS-37 COHO-01 O6/05/07 PMH W BIIbOr'e BP EXPLORATION (AK) s ~ Legal Well Name: MPS-37 Common Well Name: MPS-37 Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC Rig Name: DOYON 14 6/10/2007 I 13:00 - 19:00 I 6.00 I MOB I P 19:00 - 00:00 5.00 RIGU P 1/2007 00:00 - 04:30 4.50 DRILL P 04:30 - 06:00 1.50 DRILL P 06:00 - 07:00 1.00 DRILL P 07:00 - 07:30 I 0.501 DIVRTR I P Start: 6/10/2007 Rig Release: 6/29/2007 Rig Number: 14 PRE PRE SURF SURF SURF SURF 07:30 - 08:30 1.00 DRILL P SURF 08:30 - 09:30 1.00 DRILL P SURF 09:30 - 10:00 0.50 DRILL P SURF 10:00 - 12:30 2.50 DRILL P SURF 12:30 - 17:00 4.50 DRILL P SURF 17:00 - 00:00 I 7.001 DRILL I P I I SURF 6/12/2007 00:00 - 01:30 1.50 DRILL P SURF 01:30 - 03:30 2.00 DRILL N WAIT SURF 03:30 - 06:30 I 3.00 ~ DRILL I P I I SURF 06:30 - 07:30 1.00 DRILI. N DPRB SURF 07:30 - 09:30 2.00 DRILI N DPRB SURF 09:30 - 11:00 1.50 DRILL N DPRB SURF 11:00 - 12:30 1.50 DRILL N DPRB SURF 12:30 - 17:00 4.50 DRILL N DPRB SURF 17:00 - 00:00 I 7.00 ~ DRILL I P I I SURF 6/13/2007 00:00 - 02:00 2.00 DRILL P SURF 02:00 - 07:30 5.50 DRILL P SURF 07:30 - 15:30 I 8.001 DRILL I P I I SURF 15:30 - 16:30 1.00 DRILL P SURF 16:30 - 17:30 1.00 DRILL P SURF 17:30 - 20:00 2.50 DRILL N DPRB SURF 20:00 - 20:30 0.50 DRILL N DPRB SURF 20:30 - 00:00 3.50 DRILL N DPRB SURF I6/14/2007 00:00 - 01:00 1.00 DRILL N DPRB SURF 01:00 - 06:00 5.00 DRILL N DPRB SURF Spud Date: 6/11 /2007 End: Skid rig floor. Move rig off MPS-01A down pad. Spot rig over well MPS-37 (COHO-1). Skid rig floor into drilling position. Spot and berm rock washer and prepare pits to take on fluids. Spot tiger tank. Accept rig at 19:00 6-10-07 NU diverter, riser and flow line. Mixing spud mud. Load pipe shed w/ 150 jts 4" DP and strap. Perform derrick inspection PU 150 jts of 4" DP and stand back in derrick. ~ Cut and slip drilling line - Service rig PU 17 jts. 5" hwt and drilling jars from pipe shed - Stand back in derrick Diverter Drill - Function test annular and full opening diverter valves - Perform accumulator test (John Crisp w/ AOGCC waived witness of funtion test - Ali tests witnessed by WSL Mobilize BHA to rig floor - PJSM on PU same MU BHA #1 Pre-Spud meeting - Fill lines and stack - Check for leaks Tag up at 115' - Spud in and drill f/ 115' to 250' r. POH - Stand back HWT - MU MW D- Upload same - PJSM - RU Gyro and hang sheaves - Load sources in MW D. MU flex coilars and HWDP. Dir. drill f/ 250' to 690'. 518 gpm ~ 1330 psi. W OB: 20-25 K. 70 RPM. PUW: 98 K; SOW: 93 K; ROTW: 95 K. Tq on: 2,000. Tq off: 2,000. Running gyro every connection Dir. drill f/ 690' to 782'. Running gyro on connections Circulate at low flow rate while determining directional drilling strategy to avoid close approach to existing wells. Dir. drill f/ 782' to 875'. 460 gpm ~ 1185 psi. WOB: 25-30 K. Running gyro on connections POH for BHA change PJSM - Remove sources - Download MWD LD BHA Mobilize BHA to rig floor - Strap and caliper all tools PJSM - PU MW D- Orient and upload - MU flex collars - Test MW D- MU rest of BHA and RIH to 875'. Took survey w/ MWD. Took survey w/ gyro. Dir. drill f/ 875' to 1,273'. Running gyro on every connection. 500 gpm ~ 1380 psi - WOB: 20 K- 70 RPM. PUW: 96 K; SOW: 90 K; ROTW: 92 K. Tq on: 4 K. Tq off: 2 K Dir. drill f/ 1,273'to 1,369' Wash and ream interval 1,181'-1,369' to wipe 4.65 deg/100 DL ~ 1,285' Dir. Drill f/ 1369' to 2135' - 500 gpm, t590 psi - PUW 108k - SOW 90k - Rot Wt 100k - TQ on 4k - Tq off 3k CBU 2X - 500 gpm, 1670 psi - R&R DP w/ 70 rpm - Flow check Pump out of the hole f/ 2135' to 708'. Blow down top drive Stand back HWDP and flex collars. LD and down load MWD. Break bit Clear rig floor. Mobilize BHA tools MU bit, motor and MWD. Initialize MWD. Load sources. MU Flex collars, HWDP and Jars. Shallow test MWD RIH to 2,135' Break circulation. MAD pass from 2,135' to 800'. Printed: 7/10/2007 12:09:08 PM ~ ~ ',Legal Well Name: ICommon Well Name: Event Name: Contractor Name: , Rig Name: MPS-37 MPS-37 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 6/10/2007 Rig Release: 6/29/2007 Rig Number: 14 ' 6/14/2007 06:00 - 07:00 1.00 DRILL N DPRB SURF I 07:00 - 12:00 5.00 DRILL P SURF ~ 12:00 - 00:00 12.00 DRILL P SURF 6/15/2007 00:00 - 02:30 2.50 DRILL P SURF 02:30 - 05:00 2.50 DRILL P SURF 05:00 - 06:30 1.50 DRILL P SURF 06:30 - 08:30 2.00 CASE P SURF 08:30 - 12:00 I 3.501 CASE I N I WAIT I SURF 12:00 - 15:30 3.50 CASE P SURF 15:30 - 17:00 1.50 CASE P SURF 17:00 - 19:00 2.00 CASE P SURF 19:00 - 21:30 2.50 CASE P SURF 21:30 - 23:00 1.50 CASE P SURF 23:00 - 00:00 1.00 CASE P SURF 6/16/2007 100:00 - 05:00 I 5.001 CASE I P I I SURF 05:00 - 06:00 1.00 CASE P SURF 06:00 - 06:30 0.50 CASE P SURF 06:30 - 08:30 2.00 CEMT P SURF 08:30 - 11:30 I 3.00 I CEMT I P I I SURF 11:30 - 12:00 0.50 CEMT P SURF 12:00 - 15:30 3.50 DIVRTR P SURF 15:30 - 17:30 I 2.00 I W HSUR I P I I SURF 17:30 - 22:30 I 5.001 BOPSUp P I I SURF Spud Date: 6/11 /2007 End: RIFi to 2,020'. Tag fill. Wash and ream to 2,135' Dir. Drill f/ 2,135' to 2,777' - 500 gpm, 2110 psi - PUW 130k - SOW 100k - Rot Wt 115k - TQ on 6k - Tq off 5k Dir. Drill f/ 2,777' to 3,864' (casing point as per Geologists) - 500 gpm, 2210 psi - PUW 150k - SOW 110k - Rot Wt 128k - Tq on 6k - Tq off 5k. WOB 5-20k, 70 rpm Circulate 2x BU rotating and reciprocating pipe Pump out of the hole f/ 3,864' to 780' (BHA) w/ full drilling rate RIH f/ 780' to 3770' Screw in T.D. - Break circ - As precaution, wash last stand to bottom at 3864' - CBU 3x w/ 505 gpm, 2180 psi - R&R DP w/ 80 rpm, 5k torque Continue circulating w/ 250 gpm, 650 psi while waiting on Pad 3 injection well to open back up for disposal Pump out of hole to HWT w/ fuil drilling rate C/O elevators. Stand back HWDP and Jars. LD flex collars Remove sources. Download MWD LD BHA: MW D, Stabilizer, motor, bit. Clear fioor Change bales. MU Franks fill up tool. RU to run 9-5/8" casing MU 9-5/8" shoe track (float shoe - 2 jts. casing - float coliar - 1 jt casing). RIH and fill. Check floats. Cont. running 9-5/8" 40# L-80 BTC casing to 320' Run 9-5/8" 40# L-80 BTC casing f/ 320' to 3,819'. MU landing joint w/ casing hanger. As precaution, wash down with landing joint. Land casing in landing ring. Total jts. run: 93 + 2 pup joints. Install 23 centralizers (1 per joint) on joints 1-23. Shoe ~ 3,856'. Top F.C ~ 3,772'. CBU w/ Franks fili up tool. RD Franks Tool - RU Cement head and lines Break circ. - Slowly stage up to 8 bpm 360 psi - Circulate casing volume 2x - PJSM w/ ali involved with upcoming cement Turn over to Dowell - Pump 5 bbis H20 - Test lines to 4000 psi - Pump 10 bbls CW-100 - 50 bbls 10.0 ppg Mud Push spacer - Drop bottom plug - Pump 385 bbls ASL at 10.7 ppg - 60 bbls AS1 at 15.7 ppg - Drop top plug - Displace with 10.2 ppg MOBM using Dowell pump truck - At 170 bbls away, drag chain in pits stopped (electrical) - 10 minutes to trouble shoot - Bring pumps back on at 1 bpm - Slight returns w/ 2200 psi - Continue pumping w/ 1 bpm, pressure climbing - Cement back to surface at 185 bbls away. Stop pumping w/ 195 bbls away 3100 psi - Slowly bring pressure to 3900 psi (no returns) - Hold pressure 10 mins. - Check fioats - OK - 10 bbis cement to surface - Est top of cement = 2572' - CIP at 11:30 hrs Flush lines - RD cement head - RD Dowell Flush diverter, flowline - Suck MOBM f/ landing joint and LD same - Remove flowline - ND riser - ND diverter - Remove from cellar - SIM OPS incfude RD rockwasher and remove cuttings tank in preperation for Swaco Cuttings blower unit Install FMC Ultra-Slimhole wellhead. Test to 1,000 psi x 15 min. Ok. Install tubing spool NU BOP and choke hose. Install DBL valve on annular. Remove flow line. C/O air boot. Break out cement of flow line Printed: 7/10/2007 12:09:08 PM ~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M PS-37 MPS-37 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Spud Date: 6/11/2007 Start: 6/10/2007 End: Rig Release: 6/29/2007 Rig Number: 14 6/16/2007 17:30 - 22:30 5.00 BOPSU P SURF 22:30 - 23:00 0.50 BOPSU P SURF 23:00 - 00:00 1.00 BOPSU P SURF 6/17/2007 00:00 - 07:30 7.50 BOPSU P SURF 07:30 - 08:00 0.50 BOPSU P SURF 08:00 - 09:30 1.50 CASE P SURF 09:30 - 10:00 0.50 CASE P SURF 10:00 - 11:30 1.50 CASE P SURF 11:30 - 14:30 3.00 CASE P SURF 14:30 - 15:00 0.50 CASE P SURF 15:00 - 17:00 2.00 CASE P SURF 17:00 - 22:30 5.50 CASE P SURF 22:30 - 23:30 1.00 CASE P SURF 23:30 - 00:00 0.50 CASE P SURF 6/18/2007 00:00 - 03:30 3.50 CASE P SURF 03:30 - 05:30 2.00 CASE P SURF 05:30 - 06:30 1.00 CASE P SURF 06:30 - 08:30 2.00 CASE P SURF 08:30 - 09:00 0.50 CASE P SURF 09:00 - 10:30 I 1.501 CASE I P I I SURF 10:30 - 11:30 1.00 CASE P SURF 11:30 - 14:00 2.50 CASE P SURF 14:00 - 15:00 1.00 CASE P SURF 15:00 - 15:30 0.50 CASE P SURF 15:30 - 17:00 1.50 CASE P SURF 17:00 - 18:30 1.50 DRILL P PRODi 18:30 - 20:00 I 1.50I DRILL I P I I PRODi 20:00 - 21:00 I 1.001 DRILL I P I ! PROD1 21:00 - 22:30 I 1.501 DRILL I P I I PRODi 22:30 - 00:00 1.50 DRILL P PROD1 6/19/2007 00:00 - 01:30 1.50 EVAL P PROD1 and reinstall same - SIM OPS: Move rock washer, reposition mats and spot rock washer. Spot C.C.B unit (cuttings biower) and berm same. Clean pits for oil base mud Pull wear ring. Instail test plug RU to test BOP PJSM - Test BOP and related equipment as per BP / AOGCC regulations. Test to 250 psi low - 3,500 psi high (annular preventer to 250 psi low - 2,500 psi high). Perform koomey test. Record test on chart. Valve #6 on choke manifold leaked. Repair valve and retest - OK. Rig down testing equipment BOP test witnessed by WSL (X. Chacin), Tourpusher (T. Shones) and AOGCC Rep. (C. Scheve) SIM OPS - Spotted tank for cuttings storage. Hooked air compressor to cuttings biower. Connected cuttings blower discharge to storage tank. Puli test plug. Instali wear ring MU BHA. RIH w/ HWDP RIH to 2,000' Slip and cut drilling line. Service top drive Preparing pits for OBM. Finish installing CCB. Berm CCB, lines and cuttings storage tank RIH f/ 2,000'. Tag cement ~ 2,54f' Displace well to old OBM. Change shaker screens Clean soft cement f/ 2,541' to 3,772'. Tag fioat collar w/ 25k Circulate hole clean RU to test casing. Test casing to 2,500 psi. Lost 1,000 psi in 20 min - Retest to 2,500 psi. Lost 1,300 psi in 30 min - Retest to 1,000 psi. Pressure dropped and stabilize at 180 psi in 1.5 hr. POOH from 3,772' to PU R7TS packer. Stand back BHA PU RTTS - RIH w/ same to 3750' Screw in T.D. - Obtain Parameters - Circ. DP volume x2 w/ 30 spm, 250 psi - PUW 105k - SOW 90k Set RTTS at 3750' - RU and test casing to 2500 psi - Record on chart - Test good - Blow down, RD lines. Circulate w/ 30 spm 200 psi to balance fiuid (flowing back). POH - LD RTTS Ciean MOBM from rig floor PU and MU BHA RIH to top of F.C C~ 3,772' Drill out FC, shoe track, float shoe and rat hole. Drill 20' of new hole to 3,884' Circulate hole clean. Check MW in and MW out at 10.1 ppg. Pull back to the shoe RU lines and testing equipment. Perform FIT to 11.0 ppg EMW (surface pressure 170 psi). Hoid x 10 min. Record on chart. FIT good. RD testing equipment and lines Displace old MOBM to new 10.2 ppg MOBM, R&R pipe. Monitor well POOH from bottom to 642' (BHA) Stand back HWDP, Jars and flex collars. Break bit. LD Prinied: 7/10/2007 12:09:08 PM ~ ~ Legal Well Name: MPS-37 Common Well Name: MPS-37 Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC Rig Name: DOYON 14 Spud Date: 6/11 /2007 Start: 6/10/2007 End: Rig Release: 6/29/2007 Rig Number: 14 6/19/2007 00:00 - 01:30 1.50 EVAL P PROD1 01:30 - 02:00 0.50 EVAL P PROD1 02:00 - 03:30 1.50 EVAL P PROD1 03:30 - 05:00 1.50 EVAL P PROD1 05:00 - 06:30 1.50 EVAL P PROD1 06:30 - 08:0~ I 1.501 EVAL I P I I PROD1 08:00 - 09:00 I 1.00 I EVAL I P I I PROD1 09:00 - 11:30 2.50 EVAL P PROD1 11:30 - 13:30 2.00 EVAL P PROD1 13:30 - 16:00 2.50 EVAL P PROD1 16:00 - 17:00 1.00 EVAL P PROD1 17:00 - 18:30 1.50 EVAL P PROD1 18:30 - 20:00 I 1.501 EVAL I P I I PROD1 20:00 - 21:00 I 1.00 I EVAL I P I I PROD1 21:00 - 23:00 2.00 EVAL P PROD1 23:00 - 00:00 1.00 EVAL P PRODi 6/20/2007 00:00 - 01:30 1.50 EVAL P PROD1 01:30 - 02:30 1.00 EVAL P PROD1 02:30 - 04:00 1.50 EVAL P PROD1 04:00 - 05:30 1.50 EVAL P PROD1 05:30 - 07:00 I 1.50I EVAL I P I I PROD1 07:00 - 07:30 I 0.501 EVAL I P I I PROD1 07:30 - 10:00 2.50 EVAL P PROD1 10:00 - 12:00 2.00 EVAL P PROD1 12:00 - 13:00 1.00 EVAL P PROD1 13:00 - 14:30 1.50 EVAL P PROD1 14:30 - 15:30 1.00 ~VAL P PROD1 15:30 - 18:00 I 2.501 EVAL I P I I PROD1 18:00 - 18:30 I 0.501 EVAL I P I I PROD1 stabilizer and bit sub - Clear rig floor Mobilize BHA tools to rig floor PJSM - PU and MU coring BHA. RIH w/ coring BHA to the shoe at 3856' Space out coring string - Obtain parameters - PUW 120k, SOW 105k, ROT 115k - RIH and tag bottom ~ 3,884'. Circulate DP volume w/ 6 bpm 760 psi - Drop ball to divert fluid and pump on seat w/ 182 gpm 540 psi Coring from 3884' to 3939' w/ 60 rpm 5k torque - 182 gpm 540-640 psi - WOB 6-10k Drop ball to activate core catcher - Pump on seat w/ 182 gpm 540 psi - Observe 80 psi spike - Pump out to 3850' - Flow check well (static) POH - Stand back 5" HWT LD inner core barrels - Core # 1 Recovered 43.35' / 79% (found chunk of red rubber jammed in bbl) PJSM - MU core barrel BHA #2 RIH w/ coring assy. to shoe at 3856' Circulate DP volume w/ 4.5 bpm 400 psi - Space out coring string - Obtain parameters - PUW 125k, SOW 106k, ROT 115k - Drop ball to divert fluid and pump on seat w/ 178 gpm 500 psi - Wash to bottom ~ 3,939' Coring f/ 3939' to 3999' w/ 55 rpm 5k torque on bttm / 4k off - 150 gpm 450 psi - WOB 5-6k Drop ball to activate core catcher - Pump on seat w/ 182 gpm 540 psi - Observe 75 psi spike - Pump out to 3850' POH - Stand back 5" HWT LD inner core barrels Cont. LD core - Core # 2 Recovered 54.7' / 91 % PJSM - MU core barrel assy. #3 RIH w/ coring BHA to the shoe at 3856' Space out coring string - Obtain parameters - PUW 125k, SOW 106k, ROT 115k - Wash to bottom ~ 3,999' Circulate DP volume w/ 4.5 bpm 440 psi - Drop ball to divert fluid and pump on seat w/ 178 gpm 540 psi Cut core f/ 3999' to 4043' w/ 50 - 70 rpm 3k torque on bttm / 2k off - 157 - 178 gpm 540 - 620 psi - WOB 5-10k Drop ball to activate core catcher - Pump on seat w/ 178 gpm 600 psi - Observe 70 psi spike - Pump out to 3850' - Flow check well (static) POH - Stand back 5" HWT (POH due to poor ROP) LD inner core barrels - Core # 3 Recovered 44.4' PJSM - MU core barref assy. #4 RIH w/ coring BHA to the shoe at 3856' Space out coring string - Obtain parameters - PUW 126k, SOW 107k, ROT 119k - Wash to bottom ~ 4042' - Circulate DP volume w/ 4.5 bpm 460 psi - Drop ball to divert fluid and pump on seat w/ 180 gpm 520 psi Cut core f/ 4043' to 4103' w/ 55 rpm 3k torque on bttm / 3k off - 178 to 150 gpm, 530 to 460 psi - WOB 5-6k Drop ball to activate core catcher - Pump on seat w/ 150 gpm 600 psi - Observe 200 psi spike - Pump out to 3850' - Flow check well (static) Printed: 7/10/2007 12:09:08 PM ~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M PS-37 MPS-37 DRlLL+COMPLETE DOYON DRILLING INC DOYON 14 Spud Date: 6/11 /2007 Start: 6/10/2007 End: Rig Release: 6/29/2007 Rig Number: 14 ~ 6/20/2007 18:30 - 20:30 2.00 EVAL P PROD1 20:30 - 22:30 2.00 EVAL P PROD1 22:30 - 23:30 1.00 EVAL P PROD1 23:30 - 00:00 0.50 EVAL P PROD1 6/21/2007 00:00 - 01:00 1.00 EVAL P PROD1 01:00 - 02:30 1.50 EVAL P PROD1 02:30 - 03:00 0.50 EVAL P PROD1 03:00 - 05:00 I 2.001 EVAL I P I I PROD1 05:00 - 06:00 I 1.00 ~ EVAL I P I I PROD1 06:00 - 09:30 3.50 EVAL P PROD1 09:30 - 11:00 1.50 EVAL P PROD1 11:00 - 11:30 0.50 EVAL P PROD1 11:30 - 15:00 3.50 EVAL P PROD1 15:00 - 16:00 1.00 EVAL P PROD1 16:00 - 18:30 I 2.501 EVAL I P I I PROD1 18:30 - 19:00 I 0.50I EVAL I P I I PROD1 19:00 - 20:30 1.50 EVAL P PRODi 20:30 - 22:30 2.00 EVAL P PROD1 22:30 - 00:00 1.50 EVAL P PROD1 6/22/2007 00:00 - 00:30 0.50 EVAL P PROD1 I 00:30 - 03:00 2.50 EVAI P PROD1 I 03:00 - 04:00 1.00 EVAL P PROD1 04:00 - 05:30 I 1.501 EVAL I P I I PROD1 05:30 - 06:30 ; 1.001 EVAL I P I ! PROD1 06:30 - 11:30 ~ 5.00 ~ EVAL I P I I PROD1 11:30 - 13:00 1.50 EVAL P PROD1 13:00 - 15:00 2.00 EVAL P PROD1 15:00 - 16:00 1.00 EVAL P PROD1 16:00 - 17:00 1.00 EVAL P PROD1 POH - Stand back 5" HWT LD inner core barrels - Core # 4 Recovered 60.4' PJSM - MU core barrel assy. #5 RIH w/ coring BHA w/ 4" drili pipe f/ 615' to 1088' RIH w/ coring BHA f/ 1088' to 3850' Slip and cut drilling line - Service top drive Space out coring string - Obtain parameters - PUW 125k, SOW 107k, ROT 115k - Wash to bottom f~ 4103' - Drop ball to divert fluid and pump on seat w/ 182 gpm 430 psi - Observed 100 psi increase as bail seated Cut #5 core f/ 4103' to 4161' w/ 50 rpm - Torque 5k on bttm / 3k off - 154 gpm, 450 psi - WOB 5k Drop ball to activate core catcher - Pump on seat w/ 156 gpm 480 psi - Observe 80 psi spike - Pump out to 3850' - Flow check weil (static) POH - Stand back 5" HWT LD inner core barrels - Core #5, Recovered 52.45' / 90% PJSM - MU core barrel assy. #6 RIH w/ core barrel assy. f/ 615' to 3850' Circulate DP volume w/ 4.5 bpm 450 psi - Space out coring string - Obtain parameters - PUW 125k, SOW 107k, ROT 120k - Drop bail to divert fluid and pump on seat w/ 140 gpm 400 psi - Observed pressure increase when ball seated - Wash to bottom @ 4161' Cut #6 core f/ 4161' to 4221' w/ 55 rpm - Torque 5k on bttm / 3k off - 157 gpm, 450 psi - WOB 5k Drop ball to activate core catcher - Pump on seat w/ 170 gpm 480 psi - Observed ball seat w/ 80 psi spike - Pump out of hole to 9 5/8" shoe - Flow check well (static) POH - Stand back 5" HWT LD inner core barrels - Core #6, Recovered 52.55' / 87.6% PJSM - MU core barrel assy. #7 PJSM - Adjust core catcher - MU bit RIH w/ core barrei assy. f/ 615' to 3850' Circulate DP volume w/ 4 bpm 490 psi - Space out coring string - Obtain parameters - PUW 125k, SOW 107k, ROT 120k - Drop ball to divert fluid and pump on seat w/ 140 gpm, 370 psi - Observed 80 psi increase as ball seated - Wash to bottom ~ 4221' Cut #7 core f/ 4221' to 4255' w/ 60 rpm - Torque 5k on bttm / 3k off, 136 / 180 gpm, 400 / 570 psi - WOB 5k (cored into softer formation, core barrei jammed) Drop ball to activate core catcher - Pump on seat w/ 170 gpm, 480 psi - Observed bali seat w/ 80 psi spike - Pump out of hole to 9 5/8" shoe - Flow check well f/ 5 mins. (static) POH w/ 4" drill pipe f/ 3850' to 2600' - Continue POH ~ controlled rate, as per Geologist pulling schedule - Stand back 5" HWT LD inner core barrels - Core #7, Recovered 36.85' PJSM - MU core barrel assy. #8 - Adjust core catcher - MU bit RIH w/ coring assy. f/ 615' to 3850' Space out coring string - Obtain parameters - PUW 125k, SOW 108k, ROT 120k - Circulate DP volume ~ 4 bpm, 450 Printed: 7/10/2007 12:09:08 PM ~ ~ Legal Well Name: MPS-37 Common Well Name: MPS-37 Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC Rig Name: DOYON 14 6/22/2007 I 1&:00 - 17:00 I 1.001 EVAL I P Start: 6/10/2007 Rig Release: 6/29/2007 Rig Number: 14 PROD1 17:00 - 20:00 3.00 EVAL P PROD1 20:00 - 22:00 2.00 EVAL P PRODi 22:00 - 00:00 2.00 EVAL P PRODi 6/23/2007 00:00 - 02:00 2.00 EVAL P PROD1 02:00 - 04:00 2.00 EVAL P PROD1 04:00 - 09:00 5.00 EVAL P PROD1 09:00 - 11:00 11:00 - 11:30 6/24/2007 11:30 - 13:30 13:30 - 14:30 14:30 - 16:30 16:30 - 18:30 18:30 - 21:00 21:00 - 21:30 21:30 - 00:00 00:00 - 03:00 03:00 - 03:30 2.00 EVAL P 0.50 EVAL P 2.00 EVAL P 1.00 EVAL P 2.00 EVAL P 2.00 EVAI P 2.50 EVAL P 0.50 DRILL P 2.50 DRILL P 3.00 DRILL P 0.501 DRILL I P 03:30 - 04:00 0.50 DRILL P 04:00 - 04:30 0.50 DRILL P 04:30 - 06:00 1.50 DRILL P 06:00 - 08:00 2.00 DRILL P 08:00 - 16:00 8.00 DRILL P 16:00 - 18:00 2.00 DRILL P 18:00 - 00:00 6.00 DRILL P I6/25/2007 I00:00 - 02:00 I 2.00 I DRILL I P PRODi PROD1 PROD1 PROD1 PRODi PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PRODi PROD1 PROD1 PROD1 Spud Date: 6/11 /2007 End: psi - Wash to bottom ~ 4255' - Drop ball to divert fluid and pump on seat w/ 130 gpm, 300 psi - Observed 100 psi increase as bail seated Cut #8 core f/ 4255' to 4314' w/ 65 rpm - Torque 4k on bttm / 3k off - 150 gpm, 530 psi - WOB 5k Drop ball to activate core catcher - Pump on seat w/ 180 gpm, 630 psi - Observed ball seat w/ 120 psi increase - Pump out of hole to 9 5/8" shoe - Flow check well f/ 5 mins. (static) POH w/ 4" drill pipe f/ 3850' to 1500' Continue POH ~ controlled rate f/ 1500' to 615' - Stand back 5" HWT Break bit - LD inner core barrels - Core #8. Recovered 30.7' / 52% PJSM - MU core barrel assy. #9 - LD Split ring housing - Extension sub - MU XO sub - Bit (changed out coring BHA components to accommodate new bit) RIH w/ core barrel assy. f/ 615' to 4292' Circulate DP volume w/ 4 bpm 490 psi - Space out coring string - Obtain parameters - PUW 125k, SOW 110k, ROT 120k - Drop ball to divert fluid and pump on seat w/ 140 gpm, 370 psi - Observed 80 psi increase as ball seated - Wash to bottom ~ 4314' Cut #9 core f/ 4314' to 4349' w/ 65 rpm - Torque 4k on bttm / 4k off, 150 gpm, 550 psi - WOB 5k Pick up break off core - Pump out of hole to 9 5/8" shoe - Flow check well f/ 5 mins. (static) POH w/ 4" drill pipe f/ 3850' to 2600' - Stand back 5" HWT LD inner core barrels - Core #9, Recovered 36.3' Break off bit - LD Baker coring tools - Clear / Clean rig floor Mobilize and spot Geo-Skid - Mobilize MWD tools to rig floor MU 8 1/2" Directional BHA - MWD - Upload MWD tools Cont. Initialize MWD / MRIL - PJSM on loading nukes - Upload MWD - Upload Nukes - DC's - HWDP Attempt to power up tools - Trouble shoot connectivity issues w/ CTN tool - Circulate to warm up MWD / MRIL tools - 170 gpm, 650 psi Test CTN tooi (ok) - Cont. MU BHA - DC's - HWDP f/ 178' to 806' Flow test MW D tools - 285 gpm, 1250 psi (ok) RIH w/ 4" drill pipe f/ 806' to 3852' Break circ - Wash and ream through coring interval f/ 3852' to 4349' w/ 400 gpm ~ 2650 psi - 80 rpm, torque 4k, (No hole problems encountered) Directional drill 8 1/2" hole f/ 4349' to 4814' (TD) - PUWT 155k, SOWT 118k, RTWT 135k, 400 gpm ~ 2690 psi w/ 80 RPM - TQ 5k on bttm / 4k off Circulate bttms up x 3 w/ 400 gpm ~ 2590 psi, 80 rpm - Flow check well f/ 10 min. (static) Pump out of hole f/ 4814' to 4380' ~ drili rate 400 gpm, 2490 psi - MW D Mad pass f/ 4380' to 3980' w/ 400 gpm ~ 2490 psi, 80 rpm ~ controiled rate 100ff/hr Cont. MW D mad pass f/ 3980' to 3845' w/ 400 gpm ~ 2450 psi - 80 rpm, torque 4k Printed: 7/10/2007 12:09:08 PM '~ ~ Legal Well Name: MPS-37 Common Well Name: MPS-37 Spud Date: 6/11/2007 Event Name: DRILL+COMPLETE Start: 6/10/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/29/2007 Rig Name: DOYON 14 Rig Number: 14 6/25/2007 02:00 - 03:00 1.00 DRILL P PROD1 Circulate csg clean w/ 400 gpm ~ 2450 psi, 40 rpm 03:00 - 03:30 0.50 DRILL P PROD1 RIH f/ 3845' to 4814' (no hole problems encoutered) 03:30 - 04:30 1.00 DRILL P PROD1 Circulate hole clean, condition OBM mud w/ base oil - 400 gpm @ 2600 psi - R&R w/ 80 rpm, torque 4k - Flow check well f/ 10 mins. (static) 04:30 - 12:30 8.00 DRILL P PRODi Pump out f/ 4814' to 4550' @ drill rate - MRIL mad pass f/ 4550' to 3990' w/ 400 gpm C~3 2400 psi - UPWT 140k 12:30 - 13:00 0.50 DRILL P PROD1 RIH w/ 4" drili pipe f/ 3990' to 4814' (wash last std to bttm / no hole problems observed) 13:00 - 14:00 1.00 DRILL P PROD1 Circulate hole clean w/ 400 gpm ~ 2590 psi - 80 rpm, torque 4k - PUWT 155k, SOWT 120k, ROWT 135k 14:00 - 19:00 5.00 DRILL P PROD1 Function test Geo-skid / calibrate tools - Flow check well f/ 10 min. (static) Pump out f/ 4814' to 4550' @ drili rate - Take Sperry Geo-tap pressures ~ Sensor depth: 4618' - 4604' - 4600' - 4566' - 4562' - 4548' - 4540' - 4419' - 4410' - 4407' - 4276' - 4224' - 4162' 19:00 - 19:30 0.50 DRILL P PROD1 RIH w/ 4" drill pipe f/ 4263' - 4814' (washed last std to bttm / no hole problems encountered) 19:30 - 21:00 1.50 DRILL P PROD1 Circulate hole clean w/ 400 gpm ~ 2350 psi, 80 rpm, torque 4k - UPWT 155k - SOWT 120k - ROWT 136k - Flow check weil , f/ 10 min. (static) 21:00 - 23:00 2.00 DRILL P PROD1 Pump out to 9 5/8" csg. shoe ~ drill rate - Circulate bttms up - Flow check well f/ 10 min. (static) Pump dry job 23:00 - 00:00 1.00 DRILL P PROD1 POH w/ 4" drili pipe f/ 3850' to 1950' 6/26/2007 00:00 - 01:30 1.50 DRILL P PROD1 Cont. POH f/ 1948' to 805' - Std back HWDP in derrick 01:30 - 04:30 3.00 DRILL P PROD1 PJSM - Download MWD - MRIL - Remove Nuke sources 04:30 - 05:30 1.00 DRILL P PROD1 LD BHA - MW D/ MIRL tools - Nukes - Geo tap equip - Clear / ' Glean rig floor ' 05:30 - 07:00 1.50 EVAL P PROD1 PJSM w/ SLB - Moblize wireline tools to rig floor - RU SLB wireline equipment / Hang WL sheave 07:00 - 08:30 1.50 EVAL P PROD1 MU SLB wireline tools run #1 - RES / GR / ND / FCS / NGT 08:30 - 12:30 4.00 EVAL P PROD1 RIH w/ wireline to 4813' (W LD) Log f/ 4813' to 3851' 12:30 - 13:00 0.50 EVAL PROD1 POH w/ wireline - LD tools , 13:00 - 14:30 1.50 EVAL P PRODi Mobilize tools - MU wireiine tools for Run #2 - OBMI / Sonic I scanner / GR - Calibrate, Data test same ~ 14:30 - 19:30 5.00 EVAL P PROD1 RIH w/ wireline to 4813' (WLD) Log f/ 4813' to 3850' 19:30 - 20:00 0.50 EVAL P PROD1 POH w/ wireline - LD tools 20:00 - 22:00 2.00 EVAL P PROD1 Mobilize tools - MU wireline tools for Run #3 - CST / Side wail coring ~ 22:00 - 00:00 2.00 EVAL P PRODi RIH w/ wireline to 4316' - Take side wall cores f/ 4316' to 4272' i 6/27/2007 00:00 - 01:00 1.00 EVAL P PROD1 Cont. taking side wall cores, 45 shots attempted f/ 4316' to 4272' (WLD) 01:00 - 01:30 0.50 EVAL P PROD1 POH w/ wireline - LD toois - RD wireline sheave - Clear rig floor (confirmed w/ SLB all shots fired / side wall cores recovered = 44 out of 45 total or 98%) 01:30 - 02:30 1.00 DRILL P PROD1 MU 8 1/2" cleanout assy - Bit / F~oat sub / Stab / DCs / Jars ', 02:30 - 03:00 0.50 DRILL P PRODi RIH w/ HWDP from derrick U 643' 03:00 - 04:30 1.50 DRILL P PROD1 RIH w/ 4" drill pipe f/ 643' to 3850' 04:30 - 06:30 2.00 DRILL P PROD1 Slip and cut drilling line - Service top drive, Crown and Biocks 06:30 - 07:00 0.50 DRILL P PROD1 RIH w/ 4" drll pipe 3784' to 4814' (wash last sid to bttm / hole , in good shape) ~i 07:00 - 08:30 1.50 DRILL P PROD1 Circulate well clean / condition OBM w/ base oil w/ 400 gpm @ I 2050 psi - Flow check well f/ 5 min. (static) Printed: 7/10/2007 72:09:08 PM ~ ~ Legal Well Name: Common Well Name Event Name: Contractor Name: j Rig Name: I 6/27/2007 I 08:30 - 10:00 10:00 - 11:00 MPS-37 MPS-37 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 1.50I DRILL I P 1.001 DRILL I P Spud Date: 6/11/2007 Start: 6/10/2007 End: Rig Release: 6/29/2007 Rig Number: 14 PROD1 PRODi 11:00 - 12:30 1.50 DRILL P PROD1 12:30 - 14:00 1.50 EVAL P PROD1 14:00 - 15:00 1.00 CASE P PROD1 15:00 - 18:00 3.00 CASE P PROD1 18:00 - 19:30 1.50 CASE P PROD1 19:30 - 00:00 4.50 CASE P PRODi 6/28/2007 00:00 - 04:00 4.00 CASE P PRODt 04:00 - 04:30 0.50 CASE P PROD1 04:30 - 05:00 I 0.501 CASE I P I I PROD1 05:00 - 05:30 0.50 CASE P PROD1 05:30 - 06:00 0.50 CASE P PROD1 06:00 - 07:00 1.00 CASE P PROD1 07:00 - 08:00 I 1.001 CEMT I P I I PROD1 08:00 - 08:30 I 0.501 CEMT I P I I PROD1 08:30 - 10:00 I 1.501 CEMT I P I I PROD1 10:00 - 12:00 ~ 2.00 ~ CEMT ~ P ~ ~ PROD1 12:00 - 13:00 I 1.001 CEMT I P I I PROD1 13:00 - 14:30 1 1.501 CASE I P I I PROD1 Pump out of hole ~ drill rate f/ 4814' to 3784' - PUWT 137k - SOW7 115k CBU / Circulate 9 5/8" csg - Flow check weil f/ 10 min. (static) Pump dry job POH w 4" drill pipe f/ 3784' to 643' Stand back in derrick - HWDP / DCs - Clear / clean rig floor Pull wear ring - Install 7" test joint / test plug Change out top VBRs to 4 1/2" x 7" rams - RU test equipment - Install test plug - Test 7" rams 250 psi low / 3500 psi high - 5 min. each tesf - Record on chart - RD test equipment - Pull test piug Mobilize csg equipment - RU to run 7" 26# L-80 BTC-M casing Run 7" 26# L-80 BTC-M to 2720' w/ 2 straight blade centralizers w/ stop in middle of each jt. #1 -#34, Baker-Lok connections on top FC, top / bttm on Baffle adapter and ES cemter Con't Run 7" csg f/ 2720' to 4753' Hi-line power went down - Start rig cats / Go on rig power until power issues are resolved MU landing joint - washed down to 4793' and land 7" csg w/ franks tool - 30 spm ~ 500 psi - PUWT 155k - SOWT 130k (no hole problems encountered) Circulate and condition bttms up w/ franks tool LD franks tool - MU HES cement head / lines Circulate and condition hole f/ cement job while having PJSM w/ SLB, Veco truck drivers, rig crew Give to SLB Pump 5 bbls H20 Test lines to 3000 psi Pump 26.5 bbls Mud push ~ 12.0 ppg Pump 61.3 bbls "G" 15.8 cement Drop top plug SLB displaced cement w 169 bbls 9.4 brine water ~ 5 bpm - Slow pumps to 2 bpm / 1180 psi last 10 bbis - Bumped plug w/ 1900 psi - Cement in place ~ 08:30 hrs. - Checked floats - good (Reciprocate casing throughout cmt job) - Pressure up on ES cementer to open - Opened C~ 3200 psi Pump down casing w/ clean sea water taking returns up annulus through ES cementer to clean cement out of annulus and circ clean - 60 SPM ~ 380 psi (-20 bbls Mud push, trace cement and contaminated OBM observed ~ surface) - Continued circulating out 9.4 ppg brine until clean seawater returned to surface RU Hot Oil pump truck - Line up on cement line - Pump 62 bbls diesel - Tum back over to rig - Pump 34 bbls 9.4 ppg inhibited brine water - Drop ES closing plug - Pump 126 bbls seawater to displace diesel and inhibited brine water into annulus and close ES Cementer - Bumped plug w/ 1200 psi - Slowed to 3 bpm last 10 bbls - Held pressure f/ 10 min. (good) UD cement head - Casing running tools - Backout and UD landing joint - LD same - Drain stack FMC install 7" packoff - FMC Tested packoff U 5000 psi f/ 10 min (good) Printed: 7/10/2007 12:09:08 PM ~ ~ Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: MPS-37 MPS-37 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Spud Date: 6/11/2007 Start: 6/10/2007 End: Rig Release: 6/29/2007 Rig Number: 14 6/28/2007 14:30 - 15:30 1.00 CASE P PROD1 15:30 - 17:00 1.50 CASE P PROD1 17:00 - 18:30 1.50 CASE P PROD1 18:30 - 21:00 2.50 CASE P PROD1 21:00 - 22:00 1.00 CASE P PROD1 22:00 - 23:30 1.50 CASE P PROD1 23:30 - 00:00 0.50 CASE P PROD1 6/29l2007 100:00 - 00:30 I 0.501 CASE I P I I PROD1 00:30 - 01:30 1.00 CASE P PROD1 01:30 - 02:00 0.50 CASE P PRODi 02:00 - 02:30 0.50 CASE P PROD1 02:30 - 03:30 1.00 CASE P PROD1 03:30 - 04:30 I 1.00 I CASE I P I I PROD1 04:30 - 05:00 I 0.501 CASE I P I I PROD1 05:00 - 09:30 4.50 CASE P PROD1 09:30 - 11:00 1.50 CASE P PROD1 11:00 - 12:00 1.00 RUNCO RUNCMP 11:00 - 15:30 4.50 RUNCO RUNCMP 15:30 - 16:30 1.00 RUNCO RUNCMP 16:30 - 17:00 I 0.501 RUNCOApIP I I RUNCMP 17:00 - 17:30 0.50 RUNCO~ RUNCMP 17:30 - 19:00 1.50 RUNCO RUNCMP 19:00 - 21:00 2.00 RUNCO RUNCMP 21:00 - 22:00 I 1.001 RUNCOI~ I I RUNCMP 22:00 - 22:30 I 0.501 RUNC0111~ I I RUNCMP 22:30 - 00:00 I 1.501 RUNCONIP I I RUNCMP Ciear rig ffoor of all casing and cement+ng tools Instali test plug - Change top rams to 2 7/8" x 5" VBRs RU test equip. - Test top rams to 250 psi low / 3500 psi high f/ 5 min each test - Record on chart - LD test plug - Install wear bushing LD 6 3/4" Drill collars and 5" HWDP MU 6" cleanout BHA - 6" Bit / Bit sub / XO / 4 3/4" DCs / Jars RIH w 4" drill pipe f/ 188' to 3300' Circulate bttms up w/ 7 bpm ~ 610 psi (circ out trip air prior to pressure testing csg) RU test equip. - Test casing fe~ 3330' / above ES cementer to 1000 psi f/ 10 min (good) - Record on chart - RD test equip. Tag ES cementer ~ 3372' - Drill out ES cementer RIH f/ 3374' to baffle plate adapter ~ 4379' Circulate hole clean prior to testing casing w/ 6 bpm ~ 510 psi RU test equip. - Test 7" casing to 3000 psi f/ 30 min (good) - Record on chart - RD test equip. Prepare mud pits f/ displacement - Take on brine in pits / PJSM / Mix spacer Pump 30 bbls Hi-Vis spacer - Displace well w/ clean 9.4 ppg brine POH w/ 4" drill pipe - LD drill pipe 1 x 1 to pipe shed LD BHA - Jars - HWDP - Xo - Sub - Bit - Pull wear bushing RU tubing equpment - PJSM on running 3 1/2" tubing RIH w/ 3 1/2" 9.3# L-80 IBT-M tubing to 2529' MU landing joint w/ FMC hanger - Land 3 1/2" tbg - RILDS - Install TWC RU lines and test equip. - Test TWC to 1000 psi from below f/ 5 min (ok) Record on chart Clear rig floor - LD tubing tools PJSM - ND BOPE / choke / riser / flowline - Stand back same NU FMC adapter flange - FMC tested metal seal to 5000 psi f/ 10 min. - NU tree - Test to 3000 psi f/ 5 min (ok) Record on chart - Pull TWC RU Hot oil pumping unit - Pumped 85 bbls diesel freeze protection down 3 1/2" x 7" annulus w/ 2 bpm ~ 850 psi Instal! Back pressure valve - Test f/ below to 1000 psi f/ 5 min (ok) - Change out Saver sub RD double annulus valve / lines - Install tree blind flanges w/ guages - Secure tree and cellar - Prepare rig for move - Release rig for move ~ 00:00 hrs. Printed: 7/10/2007 12:09:08 PM Printed: 7/10/2007 12:09:32 PM Page 1 of 1 ~ ~ ~ Halliburton Company Survey Report ~~~ ~€~ ti: ~~ . t . ,~N,,, ~ , ,~ ~,~; ~~• ~r~1~~ ~ ' ~~,~e ~~ ~t ~s : ~; rag~ ~ ? ~~l~~t~ t+~EIT1~' Po~rit M P S~~f ~ r i ~ Ct1^dr~~'~~'~~~~ i 0fereltCe ~ ~ ~C~I I~uh+IPS ~7, ~"ru$ ~' ~ ,~? ~ ~ ~ ` ~ "~ ~ ~~~ ~ '~ ~r ~ t S P,~d ~ Ver[ical(T~}~ td t~P~ ~Y~~ Jr~~ 1 RFell %~ut~~a~~ ~ '~. ~ ~ , . ~ , V~lell (~: I~.~,1~ yt~ ~~} ,i~ ,~tt~n {V~} ~~ri~e~ - ~ ~ ~ : „K ~ . ~~I~~pA~ ~~.MF'~'-~7' " : o .~~~ : II. ~;° „ . ~ ~ ~ ~Oli M~t1i~i ~. ~~ ~ ~ICtltifiPi {;Ui'V~~G~~ ~~~~5 i : ~.~i A , ~' a r i ~ u ,~Cc1C1~ Fieid: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: WeII Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 WeIL• MPS-37 Slot Name: formerly CHOPS-01 Well Position: +N/-S -66.33 ft Northing: 5999904. 62 ft- Latitude: 70 24 36.676 N +FJ-W -794.51 ft Easting : 565551. 19 ft, Longitude: 149 27 58.458 W Position Uncertainty: 0.00 ft Wellpath: MPS-37 DrilledFrom: Well Ref. Point 50029233550000 Tie-on Depth: 33.78 ft Current Datum: MPS-37: Height 71. 88 ft Above System Datum: Mean Sea Level Magnetic Data: 6/8/2007 Declination: 23.41 deg Field Strength: 57626 nT Mag Dip Angle: 80.90 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 33.78 0.00 0.00 133.45 Survey Program for Definitive Wellpath Date: 7/9/2007 Validated: No Version: 6 Actual From To Survey Toolcode Tool Name ft ft 80.00 1284.00 MPS-37 Gyro (80.00-1284.00) CB-GYRO-SS Camera based gyro single shots 1385.63 4750.88 MPS-37 IIFR+MS+Sag ( 1385.63-47 MWD+IFR+MS MWD + IFR + Multi Station Survey NID ~1 ~t~ ~ ~' " . TV~ SysT~'~ ~ l~Ttr~ , . EIW ~p~., Map~ "'~~ ~ T~i °~ ~ "~ ~ ft , ; ~f~; ~ ~~d~g`° ' . ~~~ :` ~ . , , ,, .. , ft f~ ~ ~ ft~ 4 !''~ " ~t ~ ~ ~ " _ ft ~ . . 33.78 0.00 0.00 33.78 -38.10 0.00 0.00 5999904.62 565551.19 TIE LINE 80.00 0.60 °° 211.23 80.00 8.12 -0.21 -0.13 5999904.41 565551.07 CB-GYRO-SS 170.00 0.68 182.23 169.99 98.11 -1.14 -0.39 5999903.47 565550.81 CB-GYRO-SS 257.00 1.30 172.65 256.98 185.10 -2.64 -0.28 5999901.98 565550.93 CB-GYRO-SS 346.00 1.89 156.37 345.95 274.07 -4.98 0.43 5999899.64 565551.67 CB-GYRO-SS 436.00 2.98 139.55 435.86 363.98 -8.12 2.55 5999896.52 565553.81 CB-GYRO-SS 527.00 4.10 136.21 526.69 454.81 -12.27 6.33 5999892.40 565557.63 CB-GYRO-SS 619.00 5.52 131.59 618.36 546.48 -17.58 11.92 5999887.14 565563.26 CB-GYRO-SS 715.00 7.22 140.05 713.77 641.89 -25.27 19.25 5999879.52 565570.65 CB-GYRO-SS 810.00 8.45 151.48 807.89 736.01 -35.99 26.41 5999868.87 565577.91 CB-GYRO-SS 904.00 10.99 157.18 900.53 828.65 -50.31 33.19 5999854.60 565584.81 CB-GYRO-SS 997.00 13.64 155.11 991.38 919.50 -68.44 41.24 5999836.55 565593.03 CB-GYRO-SS 1091.00 16.27 153.52 1082.19 1010.31 -90.28 51.78 5999814.81 565603.75 CB-GYRO-SS 1189.00 20.16 154.27 1175.26 1103.38 -117.79 65.24 5999787.42 565617.45 CB-GYRO-SS 1284.00 24.58 154.03 1263.09 1191.21 -150.32 81.00 5999755.03 565633.50 CB-GYRO-SS 1385.63 28.99 146.52 1353.82 1281.94 -189.89 103.86 5999715.66 565656.71 MWD+IFR+MS 1417.43 29.07 147.15 1381.63 1309.75 -202.81 112.30 5999702.82 565665.26 MWD+IFR+MS 1515.27 31.70 145.69 1466.02 1394.14 -244.02 139.69 5999661.86 565693.01 MWD+IFR+MS 1610.18 30.94 145.68 1547.10 1475.22 -284.77 167.51 5999621.36 565721.17 MWD+IFR+MS 1707.41 30.37 144.57 1630.74 1558.86 -325.44 195.85 5999580.94 565749.87 MWD+IFR+MS 1799.12 30.77 140.20 1709.72 1637.84 -362.36 224.31 5999544.28 565778.65 MWD+IFR+MS 1888.78 32.63 133.48 1786.02 1714.14 -396.63 256.54 5999510.30 565811.18 MWD+IFR+MS 1988.65 31.89 131.81 1870.48 1798.60 -432.74 295.74 5999474.53 565850.69 MWD+IFR+MS 2083.68 31.20 130.58 1951.46 1879.58 -465.49 333.15 5999442.12 565888.38 MWD+IFR+MS 2136.61 31.12 130.64 1996.76 1924.88 -483.32 353.94 5999424.47 565909.32 MWD+IFR+MS 2230.90 30.05 128.36 2077.93 2006.05 -513.84 390.94 5999394.28 565946.59 MWD+IFR+MS 2326.00 31.03 124.48 2159.85 2087.97 -542.50 429.82 5999365.97 565985.72 MWD+IFR+MS 2424.62 31.07 123.74 2244.33 2172.45 -571.02 471.94 5999337.82 566028.08 MWD+IFR+MS 2514.03 32.09 124.33 2320.50 2248.62 -597.23 510.74 5999311.95 566067.10 MWD+IFR+MS ~ ~ . Halliburton Company Survey Report acc~ -~~„ ~~n~~~: ti~ A~ , ' ~ na~ ~1s~2t~~ ~ ~ ~ ~, - ; J: ~ar~ ~~~ ~~ ~,; . - , ~~ ~~ 7 ,~ , Fieldz h~3dr~~ Pt~~st , ~ C~'p~p r-a~~~) ~et erenee: 4ue H h~IPS 37 ~I't'ue , , AYC~~h ~ Si€e. i~l Pt S F~~d ~~ ~~I ~ ~~y~!~ ~ ~~{`~eu~e ~IPS 3~ ?i.~ ~ ~~ ~ `' '~ ~ ~E'ell~ {ulF~-37 ~ ,~ , , ~ i ~ - n, ~Az~ ~#e~ {I~E7~f3.{?G€ f~~ . , ~~ (~ ~~~ ,~, ~ '~ ) ~ ~ . ~'el~pa~s. i [~ F~'a-37 ~~; . ~ „ ~ _. e . ~ ~ ~ , :, , : ; ,, ~ ~ ; . ~ ~ : ° ~~*~j C~t~ilr~i~'~~ ', t~ ~~~ imum CUnratl~n'8 I~«- : ~ract$ ~ . . ~ , ~ zw .. ~ ; Survey 1~A fri~i ~n1 ~~~ !, i'S~S'L'VI) l~~ .: ~ ~~ ~ ~' ~ ' ~ Magl~ ll3ap~ ~~ J p'~ Ttwl ft d~ _ ~~~ u ~~; , , ~~ ~ ~ ~f~ ~; ~ i ~.~. .~ ~ . . ~f~ ~~ n .,,. . ;~; ~ , ~.. ~, ~~ ~ ~ fifi ~~ ,~. ;~;. r ~ft 2611.09 32.72 125.24 2402.45 2330.57 -626.91 553.45 5999282.66 566110.07 MWD+IFR+MS 2706.86 33.36 125.23 2482.73 2410.85 -657.03 596.10 5999252.91 566152.98 MWD+IFR+MS 2802.39 33.39 125.42 2562.51 2490.63 -687.42 638.98 5999222.90 566196.12 MWD+IFR+MS 2898.79 34.03 124.01 2642.70 2570.82 -717.88 682.96 5999192.83 566240.36 MWD+IFR+MS 2993.49 33.06 123.97 2721.63 2649.75 -747.13 726.35 5999163.96 566284.00 MWD+IFR+MS 3085.92 32.55 124.74 2799.32 2727.44 -775.39 767.69 5999136.07 566325.58 MWD+IFR+MS 3180.99 32.02 124.13 2879.69 2807.81 -804.11 809.57 5999107.73 566367.71 MWD+IFR+MS 3276.72 30.76 125.65 2961.41 2889.53 -832.62 850.47 5999079.58 566408.85 MWD+IFR+MS 3371.76 28.29 127.74 3044.10 2972.22 -860.57 888.04 5999051.96 566446.66 MWD+IFR+MS 3467.52 26.33 130.14 3129.19 3057.31 -888.15 922.22 5999024.68 566481.08 MWD+IFR+MS 3562.93 24.73 131.99 3215.28 3143.40 -915.15 953.23 5998997.96 566512.32 MWD+IFR+MS 3659.53 23.42 136.28 3303.48 3231.60 -942.54 981.52 5998970.82 566540.85 MWD+IFR+MS 3754.28 21.75 134.78 3390.96 3319.08 -968.52 1007.00 5998945.07 566566.55 MWD+IFR+MS 3792.77 20.32 132.37 3426.89 3355.01 -978.05 1017.00 5998935.63 566576.64 MWD+IFR+MS 3877.95 19.98 130.33 3506.85 3434.97 -997.43 1039.02 5998916.44 566598.82 MWD+IFR+MS 3971.38 20.33 131.24 3594.56 3522.68 -1018.46 1063.39 5998895.62 566623.38 MWD+IFR+MS 4066.38 20.36 131.33 3683.64 3611.76 -1040.26 1088.21 5998874.05 566648.39 MWD+IFR+MS 4158.28 20.38 131.42 3769.79 3697.91 -1061.40 1112.22 5998853.12 566672.57 MWD+IFR+MS 4255.77 20.45 132.59 3861.16 3789.28 -1084.16 1137.48 5998830.59 566698.04 MWD+IFR+MS 4342.64 20.43 132.48 3942.56 3870.68 -1104.67 1159.84 5998810.28 566720.57 MWD+IFR+MS 4443.05 20.34 132.49 4036.68 3964.80 -1128.29 1185.63 5998786.89 566746.56 MWD+IFR+MS 4543.22 20.26 132.15 4130.63 4058.75 -1151.69 1211.33 5998763.72 566772.46 MWD+IFR+MS 4635.47 20.12 132.06 4217.21 4145.33 -1173.03 1234.95 5998742.58 566796.27 MWD+IFR+MS 4729.21 19.98 131.41 4305.27 4233.39 -1194.43 1258.93 5998721.40 566820.43 MWD+IFR+MS 4750.88 19.95 130.52 4325.64 4253.76 -1199.28 1264.52 5998716.60 566826.06 MWD+IFR+MS ~ 4814.00 19.95 130.52 4384.97 , 4313.09 -1213.27 1280.89 5998702.75 566842.55 PROJECTED to TD ~ ~ MILNE POINT FIELD MPS-37 Geological and Operational Summary Geologists: C. Zarndt / I. Craig June 27, 2007 Well Ob_iectives MPS-37 (COHO-Ol) was designed as a pre-pilot well to an Ugnu cold heavy oil production with sand (CHOPS) pilot program scheduled for 2008/2009. The well will be tested for 3 months in the summer of 2008. Critical issues include: surface hole casing / core point pick in mudstone as per asset plan, no dog legs over 3° and no inclinations over 35° for completion purposes; cutting and retrieving ~450'md of whole core across Ugnu interval with correct MOBM fluid properties; isotube samples from Ugnu, N sand and O sand intervals; wireline logs across Ugnu and Schrader intervals; Sperry Sun Geo Tap pressures in Schrader intervals. Well Results MPS-37 (COHO-Ol) was spud on 6/ll/07. Directional issues / dog leg restrictions led to signifcant deviation from wellplan and close approach to MPS-26. Issues resolved and all surface hole targets met, including casing point pick in mudstone as per plan. Surface casing cement job interrupted by drag chain breaking; only ~lObbls of lead cement to surface. Coring operations began 6/19/07. A total of 9 cores / 465'feet of core were cut. Coring operations completed 6/23/07. Well was drilled to TD in 7 hours. Logging passes were made to obtain data over cored interval and to obtain MRIL data in two modes. Geo Tap (pressure) data (13 test points in OB, OA, NB and Ugnu) also obtained following MRIL passes. Three wireline logging runs successfully made 6/26-27/07, including obtaining 44 SWC in the lower Ugnu. Operational and Geolo~ical Summary • Well spudded 06/11/07. • Gyro surveys were collected from base of conductor (115'md) to 1284'md followed by MWD surveys (IFR corrected) to TD. • Unable to achieve surface directional plan w/ </= 3° dog legs. Wellbore deviated significantly from plan. Close approach to MPS-26 well. Problem resolved by POOH, removing all LWD tools, allowing directional sub to be closer to bit. Asset allowed higher dog legs. Extremely hard work on part of day directional driller brought wellbore back to plan line and avoided collision with other wellbores. Both target 1 and 2 were achieved, even with early directional issues. • ROP restrictions were 350fph until -400' above casing point at which point ROP maximum decreased to 150fph for real-time data quality. • Predicted DTW fault crossed above TUZC. Throw 170-200'. TD of surface hole (--20' above core point) was picked in mudstone as per plan. Asset geologist and wellsite geologists on location for casing point. • LWD Gamma Ray/Resistivity/Density/Neutron/Sonic log data collected from 200' to TD of surface hole, with NO MAD passes over slide intervals in surface hole. MAD pass data collected over above interval in which LWD tools removed far directional considerations. Some missing densiry data in small intervals in MAD interval. Tool apparently switched off and on occasionally. No obvious cause observed prior to shipping tools to shop. • Surface casing cement job completed 6/l6/07. Drag chain in pits interrupted pumping for 10-15 minutes. When resumed pumping, only got -lObbls of lead cement to surface. Remainder of cement (~1200') in casing to be drilled out. • RIH to drill cement; drilled soft cement to 2772'md. Casing test failed at 2500psi and 1000psi. POOH to PU RTTS. Casing test successful to 2500psi w/ RTTS. • FIT successful. Coring operations began on 6/19/07. See table below for cuUrecovered details. • Core #1 cut from 3884 -3939 `md. Cut 55'; ROP dropped to -Ofph. Core retrieval showed part of shoe jammed in upper core barrel. No isotube samples obtained due to inaccurate lag depths/stroke counts on SS MWD data. Recovered 43.35' ~ i • Care #2 cut 3939-3999'md (60'). Retrieval showed --5' lost/washed away? Obtained 2 isotube samples; one 5' into core and one almost at mid-point. SS MWD monitor values still grossly inaccurate. Recovered 54.T • Core #3 cut 3999-4043'md (44'). Obtained 2 isotube samples; one 5' into core and one at mid- point. SSMWD monitor values appear to be almost same as hand-calculated values. Bit warn; replace bit for Core #4. Recovered 44.4' • Care #4 cut 4043-4103'md (60'). Obtained 2 isotube sampies; one 5' into core and one at mid- point. • Care #5 cut 4103-4161'md (58'). Obtained 2 isotube samples; one 5' into core and one at mid- point. Lower 5' core (upper MB 1 sand) washed away. Sand very unconsolidated, vf grnd. • Core #6 cut 4161-4221'md (60'). Obtained 2 isotube samples; one 5' into care and one at mid- point. Core damaged; most likely due to normal / rapid trip speeds. Asset geologist decides to follow slower trip protocol in attempt to prevent above damage on subsequent cores. • Care #7 cut 4221-4255'md (34'). Obtained isotube sample 5' into core and second only ll' into core. Core jammed/ROP very slow. POOH using slow trip protocol. MWD lag depth reliably on depth. Will use MWD lag depth rather than hand-calculated BU for future isotube samples. Sand in core #7 was well consolidated through-out. Still some core damage from de-gassing. • Core #8 cut 4255-4314'md (59'). POOH using slow trip protocol. Lost 28.3' of lower M80 sand. Some evidence of conglomerate in core. Bit worn. BHI did not have third bit for hydro-lift system. Switch to conventional core / bit / catcher for Core #9. • Core #9 cut 4314 - 4349'md (35'). POOH using normal trip protocol. Coring operations completed 6/23/07. • Omni shipped core. Two representatives remained on location to sort and inventory all caring equipment. • Reamed and surveyed to base of care interval. Drilled and logged to TD of 4814'md / tvd / tvdss. Logged at 100fph ROP to obtain real-time GR/Res/Density/Neutron data to pick Geo tap points in Schrader. Logged MRIL in T1 mode (rotating mode); to ensure switched back to T1 mode after connections and surveys, rotated off-bottom for 2 minutes prior to tagging bottom and resuming drilling. • Sixty-two isotube samples collected through coring and to TD, as per plan. • After CBU, MAD passed cored interval into surface casing in rea]-time data mode to obtain same data for Geo-Tap and SWC points in the Ugnu/cared interval. Again ensured in T1 mode for MRIL by rotating 2 minutes anytime drill string was not rotating for 2-3 minutes. • Second MAD pass over cared interval into surface casing in T2 mode (non-rotating) for MRIL data. • Thirteen pressures obtained w/ Sperry Sun Geo Tap tool. Pressures in OB slightly above bubble point; OA pressures ~1140-1170psi; NB pressures -970--1140psi; Ugnu pressares -1730-40psi. Geo-Tap begun and concluded 6/25/07. • Three wireline logging runs made, including 45 SWC in lower Ugnu. Wireline logging concluded on 6/27/07, after obtaining 44 SWC of the 45 shots made ~ Core Summarv • CORE MDINTERVAL CUT RECOVERED # FROM / TOP TO / BASE (ft) (ft) % $L' fil I„1 fTtl ~OfE'S 1 3884' 3939' 55' 43.35' 79% 2 3939' 3999' 60' 54.70' 91 % 3 3999' 4043 44' 44.40' 101 % 4 4043' 4103' 60' 60.40' 101 % 5 4103' 4161' 58' 52.45' 90% 6 4161' 4221' 60' 52.55' 88% 7 422Y 4259 34' 36.85' 108% 8 4255' 4314' 59' 30.70' 52% 9 4314' 4349' 35' 36.30' 104% SUMMARY TOTAL CORE CUT 465' TOTAL CORE RECOVERED 411.7' TOTAL% RECOVERED 89% • • Isotube Gas Samplin~ Sixty-two gas samples were collected and shipped by Sperry/Halliburton far analysis at Isotech Labaratories: Isotube Gas Samnle Record Sample No: Formation Lagge d MD Lagged TVDSS Date/Time Comments No sample for first core. Stroke counter/lag depth not workin 1 Ugnu L/ UZC 3944' 349T 6/19/07 20:05 Sample caught while pumping ball down, at end of Core #2 2 Ugnu L/ UZC 395T 3509' 6/19/07 20:20 Sample caught when pump sto ed at the end of Core #2 3 Ugnu L/ UZC 4004' 3553' 6/20/07 0531 4 U nu M87 4029' 3577' 6/20/07 06:47 5 U~nu M87 4048' 3595' 6/20/07 17:03 6 U nu M87 4073' 3618' 6/20/07 17:54 7 U nu M87 4108' 3651' 6/21/07 0435 8 U~nu M87 / MA 4133' 3674' 6/21/07 02:20 9 Ugnu M80 / MB1 4166' 3705' 6/21/07 17:14 ]0 Ugnu M80/ MB 1 4191' 3729' 6/21/07 17:55 11 Uenu M80 / MB2 4226' 3761' 6/22/07 0535 12 Ugnu M80 / MB2 4251' 3785' 6/22/07 05:42 13 Ugnu M80 / MB2 4260' 3793' 6/22/07 18:41 14 Ugnu M80 / MB2 4285' 381T 6/22/07 19:20 15 Ugnu M80 / MB2 4319 3849' 6/23/07 13:06 16 Ugnu M80 / MB2 4332 3861' 6/23/07 13:26 T7 Ugnu M80 / MC 4350 3878 6/24/07 835 Start 10' sample interval 18 Uanu M-70 / MC 4360 3887 6/24/07 8:44 19 Ugnu M-70 / MC 4370 3896 6/24/07 8:51 20 NA 4380 3906 6/24/07 8:58 21 NA 4390 3915 6/24/07 9:10 22 NA 4400 3924 6/24/07 9:17 23 NB 4410 3934 6/24/07 9:25 24 NB 4420 3943 6/24/07 9:41 25 NB 4430 3953 6/24/07 9:50 26 NC 4440 3962 6/24/07 9:58 27 NE 4450 3971 6/24/07 10:08 28 NE 4460 3981 6/24/07 10:16 29 NE 4470 3990 6/24/07 10:26 30 NE 4480 3999 6/24/07 10:33 31 NE 4490 4009 6/24/07 10:46 32 NE 4500 4018 6/24/07 10:54 33 NF 4510 4028 6/24/07 ll:02 34 NF 4520 4Q37 6/24/07 ll:21 Start S sam les 35 NF 4525 4042 6/24/07 11:25 36 NF 4530 4046 6/24/07 11:28 37 NF 4535 4051 6/24/07 11:31 38 OA 4540 4056 6/24l07 11:36 39 OA 4545 4060 6/24/07 11:41 40 OA 4550 4065 6/24/07 11:46 41 OA 4555 4070 6/24/07 11:51 42 OA 4560 4075 6/24/07 11:56 ~ 43 OA 4565 4079 6/24/07 12:01 44 SBC 4570 4084 6/24/07 12:06 • • 45 SBC 4575 4089 6/24/07 12:12 46 SBC 4580 4093 6/24/07 12:21 47 SBC 4585 4098 6/24/07 12:26 48 SBC 4590 4103 6/24/07 1235 49 SBC 4595 4107 6/24/07 12:42 50 OB 4600 4112 6/24/07 12:45 51 OB 4605 4117 6/24/07 12:49 52 OB 4610 4121 6/24/07 13:07 53 OB 4615 4126 6/24/07 13:12 54 OB 4620 4131 6/24/07 13:16 55 OB? 4625 4136 6/24/07 13:21 56 OBb 4630 4140 6/24/07 13:24 57 OBb 4635 4145 6/24/07 13:28 58 OBb 4670 4178 6/24/07 13:59 30' sample intervals 59 OBc 4700 4206 6/24/07 1433 60 OBc 4730 4234 6/24/07 15:02 61 OBd 4760 4263 6124107 15:26 62 OBd 4790 4291 6/24/07 15:50 Last sample Formation To s Based on MWD data Marker Actual MD Actual TUD/TVDSS P€o TVDSS +/:- to Pro BPRF -1800 Not icked TUZC 3904 3531 /-3459 -3466 7' hi h M87F (-Ugnu Ma) 4120 3734 /-3662 -3658 4' dee Ugnu MA 4125 3739 /-3667 NF M80T (-MB1 4147 3759 /-3687 -3685 2' dee MB1 4147 3759 / -3687 NF SBF2 - Top NA 4377 3975 /-3903 -3905 2' hi h SBF1 - Top NB 4403 3999 /-3927 -3935 8' hi h Top NC 4435 4029 /-3957 NA Top NE 4447 4040 /-3968 NF Top NF 4502 4092 /-4020 NF TSBD - To OA 4538 4t26 /-4054 -4055 1' hi h Base OA/TSBC 4570 4156 /-4084 NF TSBB - Top OB 4597 4181 /-4109 -4120 11' hi h SBAS - Base OB 4624 4506 /-4135 -4140 5' hi h Operational Hi~hli~hts • Directional targets accomplished as per plan, even after significant early directional issues. • Surface casing pick accomplished even with fault throw -80' more than prognosed. • Ugnu coring very successful, recovering 89% of core cut. • Isotube samples obtained as per plan • MWD Geo Tap pressures obtained as per plan • Successful wireline runs, including obtaining 44 SWC. Onerational Dif~culties • Difficulties steering wellbore away from "close approach" limit of MPS-26 well. Had to remove all MWD tools except Directional to enable Gyro surveys closer to the bit. • Geo shack once again in precarious position. • MWD input for BU ! lag depth erroneous for significant footage due to inexperienced MWD engineers. Sample catchers need to come to location able to calculate BU and doing these calculations. MWD should not be responsible far these calculations. :U:1 1 37 ~€, ~S ~ ~~ . ~ ~ ~ ~: , ~3 ~~ - ... .,_ n /~y r'~~~ ~ Y~ ~ ~ ~-5 1 .a?,-. _ ~.~i 3 ~~ ~~~ ~ ~ ~~ ~ ~ ~ _ -^`• -..5~: - ~"~ ~~ ~ ~~~~~~ ~~ - Legal Name: MPS-37 Common Name: MPS-37 ~~ T~g~t Date` , ' T~~7yp~ , 3;, „ ~ ~ ?';~'~~st D~p~t~ ~1'N~~} 3 ~ . ~ ~ ~ _ . ~ ~"es~ ~epth',~I~} ~ . .. : 4~MW . .; j,° ' ~~ ~~rfa~e'Pressure ~~ ~~ 4eak C~ff ~r~ssur~,~E~Hp~ ~ ~~ ~ '_ EMW °, ' 6/18/2007 FIT 3,884.0 (ft) 3,486.0 (ft) 10.10 (ppg) 170 (psi) 1,999 (psi) 11.04 (ppg) ~ ~ Printed: 7/10/2007 12:09:04 PM ~ , ~ Halliburton Company Survey Report Co~npany: ~'~SP AmOCO Date: 7/J12~07 Time: 14.4~ :4S ~~~ Page: I 1 ~'e~ld: '~fut'rlne Point Co-ordinate(NE) RefeFence: ! W~IL- MPS-37, Ti'ue Nc~rttt Site: M Pt S Pad Vertical (TVD) Referenee: MF~S-37: 71.3 Welt: MPS-37 ~ Section (VS) Reference: ` Well ({~:~DN,O.OQE,133.45AZi} Welipath: 'MPS 37'~~ _ ---- -- ° ----- ~ Survey Caleulation M~thod: ~ MinimUl;rt ~urva~uGe ~ Dbs (~racle I Field: Milne Point ~ North Slope I UNITED STATES i Map System:US State Plane Coordinate System 1927 Map 7_one: Alaska, Zone 4 ~ Geo Datum: NAD27 (Clar ke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: MPS-37 Slot Name: formerly CHOPS-01 Well Position: +N/-S -66.33 ft Northing: 5999904.62 ft Latitude: 70 24 36.676 N +E/-W -794.51 ft Easting : 565551.19 ft Longitude: 149 27 58.458 W I Positiou Uncertainty: 0.00 ft ~ Wellpath: MPS-37 Drilled~From: Well Ref. Point ~ 50029233550000 Tie-on Depth: 33.78 ft Current Datum: MPS- 3T. Height 71.88 ft Above System Datum: Mean Sea Level Magnetic Data: 6/8/2007 Declination: 23.41 deg Field Strength: 57626 nT Mag Dip Angle: 80.90 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ~ ft ft ft deg 33.78 0.00 0.00 133.45 Survey Program for Definitive Wellpath Date: 7/9/2007 Validated: N o Version: 6 Actual From To Survey Toolcode Tool Name ft ft 80.00 1284.00 MPS-37 Gyro (80.00-1284.00) CB-GYRO-SS Camera based gyro single shots 1385.63 4750.88 MPS-37 IIFR+MS+Sag ( 1385.63-47 MWD+IFR+MS MWD + IFR + Multi Station Survey ' M37 Incl Aaim ' TVD Sys TVT} "' NfS E!W MapN MapE Toal ' ft deg ',deg ft fF ' ft ft' ' ft !#t 33.78 0.00 0.00 33.78 -38.10 0.00 0.00 5999904.62 565551.19 TIE LINE 80.00 0.60 211.23 80.00 8.12 -0.21 -0.13 5999904.41 565551.07 CB-GYRO-SS 170.00 0.68 182.23 169.99 98.11 -1.14 -0.39 5999903.47 565550.81 CB-GYRO-SS 257.00 1.30 172.65 256.98 185.10 -2.64 -0.28 5999901.98 565550.93 CB-GYRO-SS 346.00 1.89 156.37 345.95 274.07 -4.98 0.43 5999899.64 565551.67 CB-GYRO-SS 436.00 2.98 139.55 435.86 363.98 -8.12 2.55 5999896.52 565553.81 CB-GYRO-SS 527.00 4.10 136.21 526.69 454.81 -12.27 6.33 5999892.40 565557.63 CB-GYRO-SS 619.00 5.52 131.59 618.36 546.48 -17.58 11.92 5999887.14 565563.26 CB-GYRO-SS 715.00 7.22 140.05 713.77 641.89 -25.27 19.25 5999879.52 565570.65 CB-GYRO-SS 810.00 8.45 151.48 807.89 736.01 -35.99 26.41 5999868.87 565577.91 CB-GYRO-SS 904.00 10.99 157.18 900.53 828.65 -50.31 33.19 5999854.60 565584.81 CB-GYRO-SS 997.00 13.64 155.11 991.38 919.50 -68.44 41.24 5999836.55 565593.03 CB-GYRO-SS 1091.00 16.27 t53.52 1082.19 1010.31 -90.28 51.78 5999814.81 565603.75 CB-GYRO-SS 1189.00 20.16 154.27 1175.26 1103.38 -117.79 65.24 5999787.42 565617.45 CB-GYRO-SS 1284.00 24.58 154.03 1263.09 1191.21 -150.32 81.00 5999755.03 565633.50 CB-GYRO-SS 1385.63 28.99 146.52 1353.82 1281.94 -189.89 103.86 5999715.66 565656.71 MWD+IFR+MS 1417.43 29.07 147.15 1381.63 1309.75 -202.81 112.30 5999702.82 565665.26 MWD+IFR+MS 1515.27 31.70 145.69 1466.02 1394.14 -244.02 139.69 5999661.86 565693.01 MWD+IFR+MS 1610.18 30.94 145.68 1547.10 1475.22 -284.77 167.51 5999621.36 565721.17 MWD+IFR+MS 1707.41 30.37 144.57 1630.74 1558.86 -325.44 195.85 5999580.94 565749.87 MWD+IFR+MS 1799.12 30.77 140.20 1709.72 1637.84 -362.36 224.31 5999544.28 565778.65 MWD+IFR+MS 1888.78 32.63 133.48 1786.02 1714.14 -396.63 256.54 5999510.30 565811.18 MWD+IFR+MS 1988.65 31.89 131.81 1870.48 1798.60 -432.74 295.74 5999474.53 565850.69 MWD+IFR+MS 2083.68 31.20 130.58 1951.46 1879.58 -465.49 333.15 5999442.12 565888.38 MWD+IFR+MS 2136.61 31.12 130.64 1996.76 1924.88 -483.32 353.94 5999424.47 565909.32 MWD+IFR+MS 2230.90 30.05 128.36 2077.93 2006.05 -513.84 390.94 5999394.28 565946.59 MWD+IFR+MS 2326.00 31.03 124.48 2159.85 2087.97 -542.50 429.82 5999365.97 565985.72 MWD+IFR+MS 2424.62 31.07 123.74 2244.33 2172.45 -571.02 471.94 5999337.82 566028.08 MWD+IFR+MS 2514.03 32.09 124.33 2320.50 2248.62 -597.23 510.74 5999311.95 566067.10 MWD+IFR+MS ~ Halliburton Company Survey Report • Company: BP AmOCO Date: 7/g/2dQ7 Time: 14:41:46 Page: : 2 Fiela: ~'~~Milne Point Caorc~inate(I~1E) RePei~ence: WeIL MPS-37, ~f'i'ue North Site: IM Pt S Pad Uerta~caF (TVi;I) Reference: ' MPS 3~: 71.9 WeIL• MPS-37 Section (V5) Reference: ' Well (d:~ON,~.QpE,133.4~aAzij Wellpath: ' MPS 37 i Surtiey Calcvlation Methocl: '~~ Minimu~rt CUtv~tUCe ~b: Oracle Survey MD Incl Azirn ' TVU ' Sys `t"~ ' N13 EIW MapN MapE Taol ' ft deg ',deg ft ft ' ft ft; ft ft 2611.09 32.72 125.24 2402.45 2330.57 -626.91 553.45 5999282.66 566110.07 MWD+IFR+MS 2706.86 33.36 125.23 2482.73 2410.85 -657.03 596.10 5999252.91 566152.98 MWD+IFR+MS 2802.39 33.39 125.42 2562.51 2490.63 -687.42 638.98 5999222.90 566196.12 MWD+{FR+MS 2898.79 34.03 124.01 2642.70 2570.82 -717.88 682.96 5999192.83 566240.36 MWD+IFR+MS 2993.49 33.06 123.97 2721.63 2649.75 -747.13 726.35 5999163.96 566284.00 MWD+IFR+MS 3085.92 32.55 124.74 2799.32 2727.44 -775.39 767.69 5999136.07 566325.58 MWD+IFR+MS 3180.99 32.02 124.13 2879.69 2807.81 -804.11 809.57 5999107.73 566367.71 MWD+IFR+MS 3276.72 30.76 125.65 2961.41 2889.53 -832.62 850.47 5999079.58 566408.85 MWD+IFR+MS 3371.76 28.29 127.74 3044.10 2972.22 -860.57 888.04 5999051.96 566446.66 MWD+IFR+MS 3467.52 26.33 130.14 3129.19 3057.31 -888.15 922.22 5999024.68 566481.08 MWD+IFR+MS 3562.93 24.73 131.99 3215.28 3143.40 -915.15 953.23 5998997.96 566512.32 MWD+IFR+MS 3659.53 23.42 136.28 3303.48 3231.60 -942.54 981.52 5998970.82 566540.85 MWD+IFR+MS 3754.28 21.75 134.78 3390.96 3319.08 -968.52 1007.00 5998945.07 566566.55 MWD+IFR+MS 3792.77 20.32 132.37 3426.89 3355.01 -978.05 1017.00 5998935.63 566576.64 MWD+IFR+MS 3877.95 19.98 130.33 3506.85 3434.97 -997.43 1039.02 5998916.44 566598.82 MWD+IFR+MS 3971.38 20.33 131.24 3594.56 3522.68 -1018.46 1063.39 5998895.62 566623.38 MWD+IFR+MS 4066.38 20.36 131.33 3683.64 3611.76 -1040.26 1088.21 5998874.05 566648.39 MWD+IFR+MS 4158.28 20.38 131.42 3769.79 3697.91 -1061.40 1112.22 5998853.12 566672.57 MWD+IFR+MS 4255.77 20.45 132.59 3861.16 3789.28 -1084.16 1137.48 5998830.59 566698.04 MWD+IFR+MS 4342.64 20.43 132.48 3942.56 3870.68 -1104.67 1159.84 5998810.28 566720.57 MWD+IFR+MS 4443.05 20.34 132.49 4036.68 3964.80 -112829 1185.63 5998786.89 566746.56 MWD+IFR+MS 4543.22 20.26 132.15 4130.63 4058.75 -1151.69 1211.33 5998763.72 566772.46 MWD+IFR+MS 4635.47 20.12 132.06 4217.21 4145.33 -1173.03 1234.95 5998742.58 566796.27 MWD+IFR+MS 4729.21 19.98 131.41 4305.27 4233.39 -1194.43 1258.93 5998721.40 566820.43 MWD+IFR+MS 4750.88 19.95 130.52 4325.64 4253.76 -1199.28 1264.52 5998716.60 566826.06 MWD+IFR+MS 4814.00 19.95 130.52 4384.97 4313.09 -1213.27 1280.89 5998702.75 566842.55 PROJECTED ta TD ~ ~. 31-Ju1-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPS-37 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 33.78' MD Window / Kickoff Survey 0.00' MD (if applicable) Projected Survey: 4,814.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date 23 ~ Signed ~ Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) o~,p7- ~S~'Z ~ ~ ~ ~ ~~~~~/~ ~~~~11 ~j~..i~ 1-.. ~ i ^1~ ~~"~' i*~l~~1~~ti Sondra Stewman r~~+~+~~; Technicai Assistant $P Exploration (Afaska) inc. ACT Rrilling & WeUs 90U East Benson Boutevard P.O. 'Bax 196612 Anchorage. Alaska 99599-6612 : (9Q7a 561-5311 ~ ~ ~ '<~~..,~~~ June 7, 2007 ~,~ ~y ~ ~ Afaska Oil & Gas Conservation Cammissian 333 West 7'" Avenue, Suifie 10Q ,4ncho~age, Alaska 99501 ` Reference: Well Name Change - MPS-COHO-01 ' airect: {9073 56~1-a75a ' Sondra.Stewman~bp.com Mr. Art Saitmarsh: The aperatar resp~ctfull}r requests that the fc~t~c~wi~tg wvell within the Milne>Paint `Ur~it be re-named as f~ilavus: Current Nam~ 1~~w;Name Perrni# # API #` MPS-COHC}-01 MPS-37 _~- _ ~~; ' ,~' 5Q-029-23355`C?Q-OU' The ne~rv well name carrectly identifies the surface lacation ~rom which th~ w~#I is to ' be drill~d. Thank you ~r~ry much for your assistar~ce in this rnatter. Sincerely, L::,.~.c~-~... ^• ,w ~_...__..._.~. 'Sondra tewman D'tstribution Well Files PDC- Parnter Distribution F. R. Bell & Associates - Reissue As-Built MPU Pad Engineer MPU Drilling Engineer ~ ~ ~ ~ w~:.~ ~ ~ ~ ~ ~r ~-y ~ ~~~a ~r~°~ ~ q ~ F ~° a ~ rT ~ i+ ~ 4 ~ ~ l,~3, 1 3 ~ ~ ~i 7 ~ k _ "~ ~~ ~ ~ e ~ ~ ~ ~~ ~'` y ~~ ~ ¢ ~ ~ p ~ '~~yyy p '~ 3~J i ~ t ~~ s ~ i ~ g iL_m e e .~ i g` ~~ ` ~ ' ..N ~~~~4 4 A ~ ' ,. l ~ R~~ ~ ~ t S 1 ~ / 7 1 ~ ~ ' .. .., ,w,~ p~Jg ~:..,/,.,. .-~ i_.t 6..a a,...: i N : ~_ ' i, t ~x f~..t ~.,". C011T5ERQ~~IO C ~ Ip~ Dan Kara Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 SARAH PALIN, GOVERNOR 333 W. 7thAVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Milne Point Unit, Ugnu Unde~ned Oil Pool, MPS-COHO-O1 BP Exploration (Alaska) Inc. Permit No: 207-052 Surface Location: 3240' FSL, 459' FEL, SEC. 12, T12N, RlOE, UM Bottomhole Location: 2058' FSL, 803' FWL, SEC. 07, T12N, R 11 E, UM Dear Mr. Kara: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by Iaw from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.Q5 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, an . Seamoi~nt Commissioner DATED this ~ day of April, 2007 cc: Department of Fish c`~ Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~~~ ALAS~IL AND GAS CONSERVATION COMMI~N ~/-3~ PERMIT TO DRILL RECEI~7E~ APR 1 8 2007 20 AAC 25.005 Aiaska Qil & Gas Cons, Commission 1 a. Type of work ~ Drill ^ Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ~ Multiple Zone ^ Stratigraphic Test ~ Development Oil ^ Single Zone 1 c. Specify if well is propose . ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ~ Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: MPS-COHO-01 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 4791' ND 4402' 12. Field / Pool(s): Milne Point Unit / Ugnu 4a. Location of Well (Governmentai Section): Surface: 3240' FSL 459' FEL SEC 12 T12N R10E UM 7. Property Designation: ADL 380110 , , . , , , ~P~anned> Top of Productive Horizon: 2204' FSL, 646' FWL, SEC. 7, T12N, R11 E, UM 8. Land Use Permit: 13. Approximate Spud Date: June 15, 2007 Total Depth: 2058' FSL, 803' FWL, SEC. 07, T12N, R11 E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 2020' 4b. Location of Well (State Base Plane Coordinates): Surface: x-565552 y-5999905 Zone-ASP4 10. KB Elevation Planned (Height above Gl): 54' feet 15. Distance to Nearest We11 Within Pool: 815' 16. Deviated Wells: Kickoff Depth: p feet Maximum Hole An le: 30 de rees 17. Maximum Anticiga~ft d Pressures in psig (see 20 AAC 25.035) Downhole: fO~lo~ SurFace: I..~4.5 ~B 18s asin Pr rarn: 5 e ficatio ns To = Settin De th -'B ttom uanf of Cem~nt c:f or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta e data 48" 20" 92# H-40 Weld 120' SurFace Surfa e 120' 120' 26 sx Arctic Set A rox. 12-1/4" 9-5/8" 40#/47# L-80 BTC 3845' Surface Surfa e 3845' 3505' 47 sx AS Lite 348 sx AS1 8-1/2" 7" 26# L-80 BTC-M 47 1' Surface S rfa 4791' 4402' sx I s'G' ~ 19. PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD ND Conductor / Structural Surface Intermediate Produc i n Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ~ Filing Fee, $100 ^ BOP Sketch ~ Property Plat ^ Diverter Sketch ~ Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ~ Drilling Fluid Program ~ 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Printed Name Dan Kara ~ ; Si nature ~ ` ~`-~~ Contact John Rose, 56a-5271 Title Senior Drilling Engineer Prepared By Name/Number. Phone 564-5667 Date ~~ cJ~ Sondra Stewman, 564-4750 Commission Use ~nl Permit To Drill Number: 0~05o?O API Number: so-oa9~~3s'SooaD Permit A ro al Date: See cover letter for otherre uirem nts Conditions of Approval: / If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: a1 Samples Req'd: ~ Yes L~ No Mud Log Req'd: O,Yes I,U No HZS Measures: Yes ^ No Directional Survey Req'd: ~ Yes ^ No Othe~: ~Sv~ ~ ~ W~ ~~~, 4 APPROVED BY THE COMMISSION Date ,7 ~ , COMMISSIONER Form 10-401 Revised 12/2005 ~ ~ ~ ' Submit In DupliCate ~~~~~i ~~~ ~ ~ To: Tom Maunder, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: John Rose, ODE h~ Date: April 17, 2007 ~~J Re: MPS-Coho-Ol Permit to Drill The Coho-O1 is a Milne Point S-Pad Ugnu production test well which is scheduled to be drilled by Doyon Rig #14 with an estimated spud date of 06/04/07. The basic drilling plan is to spud the. well with a 12-1/4" bit and drill to the surface hole TD at 3845' MD where 9-5/8" surface casing will be run and cemented to surface. An 8-1/2" hole will then be drilled and cored with oil based mud to the final well TD of 4791' MD where open-hole E-line logs will be run as required. A 7" casing string will then be run to the final well TD and cemented to ~464' inside the 9-5/8" casing using a DV collar in the 7" casing at ~3381' MD to clear the excess cement from 9-5/8" x 7" annulus. The 9-5/8" x 7" outer annulus will then be freeze protected to ~2200' with diesel, through the DV collar. A clean-out run will be made with a 6" clean-out assembly to the PBTD at ~4711' MD displacing the well to solids-free 9.4 ppg NaCI brine. A~2500' long 3-1/2" circulation string will be run and landed prior ND BOP and NU tree leaving a~100' air-gap on top of the well in both the tubing and the IA. (NOTE: The planned air-gap and 9.4 ppg brine combine to provide an effective freeze-back prevention system for tubing and IA in this well.) At this point, the well will be suspended until all well data has been analyzed and a path-forward production testing strategy has been developed. Please note the attached Wellplan Summary for specific details concerning the drilling and suspension of this appraisal well: MP-COHO-01 Test Page 1 4/17/2007 ~ ~ Well Name: MPS-Coho-01 Ugnu Production Test Well Drilling and Evaluation Plan Summary T e of Well: Appraisal Well Surface Location: 2040' FNL and 459~ FEL (As Proposed) Section 12, T12N, R10E UM ' ' E = 565,552 N = 5,999,905 T1 - 9-5/8" Casing Point 2262° FSL and 584~ FWL Section 7, T12N, R11 E UM E= 566,604 N= 5,998,936' Z=-3432' TVDSS T2 - M80T Top 2204' FSL and 646' FWL Section 7, T12N, R11 E UM E= 566,666' N= 5,998,879' Z=-3685' TVDSS T3 - TD (Base OB plus 200' MD) 2058' FSL and 803` FWL Section 7, T12N, R11 E UM E= 566,824' N= 5,998,734' Z=-4330' TVDSS Distance to nearest Unit 2020' - shortest distance from BHL to MPU/PBU unit Boundary boundary Distance to nearest reservoir penetration $15' MB-1 from Coho to MPS-08 AFE Number: Estimated Start Date: 06/15/07 Ri : Do on 14 Ri da s to com lete: 16 MD: 4791 ° TVD: 4402~ Max Inc: 30° KOP: 250' KBE: 54' Well Desi n: Ultra Slimhole Ob'ective: U nu M Sands Core/Production & Schrader Data Mud Program: 12-1/4" Surface Hole (0' - 3845' MD): FW Spud Mud Densi PV YP Ph API Filtrate Chlorides : m .I 8.6-9.8 10 - 25 30 - 50 8.5 - 9.5 NC-8 < 1000 8-1/2" Drill/Coring (3844' to 4791'): 100% Mineral Oil-Based Core Fluid Qensit PV YP " H HTHP Filtrate % Oil 8.6-10.2 20-35 20 - 30 N/A < 2 100 Waste Disposal: There will be no annular injection associated with this drilling operation. All Class 2 "exempY' drilling waste (mud and cuttings) will be transported to the Prudhoe GNI at DS#4 for disposal, however, some Class 2"exempY' liquids may be transported to KRU 1 R-18 for injection if needed. All Class 1 waste should be sent for disposa! at PBU Pad 3. MP-COHO-01 Test Page 2 4/17/2007 C~ Casing/Tubing Program: L _J Hole Size Csg/Liner Wt/Ft Grade Conn Burst Collapse Length Top Bottom Diam MD/ MD/ TVDrkb TVDrkb 48-in 20-in 92 H-40 Weld 1530 520 120-ft 0 120' / Insulated 120' 12.25-in 9 5/8-in 40 L-80 BTC 5750 3090 3845' 0 3845'/ &/or 3505' 47 8.5-in 7-in 26 L-80 BTC-M 7240 6600 4791' 0 4791'/ 4402' 3.5-in 9.2 L-80 IBT-M 10160 10540 2500' 0 2500'/ 2315' Cement Program: Casin Size 9-5/8", 40#, L-80, BTC Surface Casin Basis Lead cement = 3200' MD to surface with 40°/a excess below the PF and 150% excess above through the PF. Tail cement = 645' MD above shoe lus 40% excess Total Cement Volume: 426 bbls Wash ~5 bbl water S acer ~50 bbls of MudPush 11.0 Lead 376 bbls, 475 sxs of Arctic Set Lite at 10.7 4.45 ft /sx Tail 50 bbls, 348 sxs AS1 mixed at 15.7 Ib/ al 0.93 ft /sx Tem BHST = 55°F Casin Size 7", 26#, L-80, BTC-M Casin Tail cement: 946' of 7" x 8-1/2" annulus plus 40% Excess, plus 80' of 7", Basis 26# shoe track, plus 500' of 7" x 9-5/8" liner lap, plus 200' of 9-5/8" x 4" drill i e annulus. Total Cement Wash ~5 bbl water Volume: 59.2 bbl S acer ~25 bbls of MudPush 11 A Tail 59.2 bbls, 286.5 sxs "G" mixed at 15.8 Ib/ al & 1.17 ft /sx Tem BHST = 75°F ,-~- °~ ~-~5 ~X ~Q~ `~ ,1Zc~~ ~~ ~ / 3~~~1 MP-COHO-01 Test Page 3 4/17/2007 ~ Evaluation Program: ~ 12-1/4" Section Open Hole: • MWD/GR/RES • IFR/CASANDRA • Sperry InSite • DEN/NEU w/ACAL • Sonic (BAT) ~ Gyro • IFR/CASANDRA 8-1/2" Section Open Hole: • MWD/GR/RES • IFR/CASANDRA • Sperry InSite • DEN/NEU w/ACAL • MRIUGeo Tap • Isotubes in Ugnu and Schrader • E-Line Logs at TD o PEX/ECS/RT Scanner o OBMI/NGT/Sonic Scanner • Whole U nu Core Cased Hole: • GR/USIT/CBL Post ri E-line work Formation Markers: (7) Formation Tops(TVDss) and Estimated Pore Pressures ~ FOIm[ltl0/t Estimuted Formation Tops (TVDss) Uneertainty (feet) Hydrocurbon Bearing (Yes/No) Est. Pore Press. ~ (Psi) Est. Pore Press. (ppg EMW) NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation to s are re uired from surface to TD for all new wells BPRF -1800 +/- 200 ft. No 782 835 TIJZC -3466 +/- 50 fi Yes 1505 835 M87F -U nu Ma -3658 +/- 50 ft Yes 1588 8.35 M80T (-MBl) -3685 +/- 50 ft Yes 1600 835 SBF2-To NA -3905 +/- 35 ft. Yes 1696 835 SBFI-To NB -3935 +/- 30 ft. Yes 1228 - 1842 6.0 - 9.0 TSBD-To OA -4055 +/- 25 ft Yes 1160 - 1687 SS - 8.0 TSBB-To OB -4120 +/- 35 ft Yes 1178 - 1714 5S - 8.0 SBAS-Base OB -4140 +/- 40 ft Yes l 184 - 1722 SS • 8A Well TD Criteria TD is 200' md below base OB to ensure all LWD and wireline tools cross the base of sand. (I.e., ??ft TVD, ??ft Rathole, etc.) Comments MP-COH0-01 Test Page 4 4/17/2007 ~ Recommended Bit Program: ~ BHA Hole Size Depth `(MD) F+~atage Bit Type TFA GPM 1 12-1/4" 0- 3845' 3845' Baker Hughes MXL1 .9 - 1.0 550-650 2 8-1/2" 3845' - 4791' 946' Baker Hughes MXL1 .7 -.8 450-500 Well Control: Intermediate/Production hole: • Maximum anticipated BHP: 1696 psi at 3905' TVDss (SBF2-NA) • Maximum surface pressure: 1305 psi at (Based on a full column of gas at 0.1 psi/ft) • Planned BOP test pressure: 3,500 psi • BOP Test Frequency: Every 2 weeks • Integrity tests: FIT or LOT to 11.2 Ib/gal 20' below the 9-5/8" shoe. • Kick tolerance: Infinite with 10.2 Ib/gal mud at below the 9-5/8" shoe. • Planned completion fluid: 9.4 ppg brine Drilling Hazards & Contingencies: Running Gravel/heavy clay problems have been encountered in some MPU wells. High Vis Mud should be utilized. Hydrates could be encountered. Expected potential depth for hydrates would be from base of permafrost at 2048' MD. Keep the Mud as Cool as possible. Lost Circulation • Lost Circulation is not anticipated as a major problem. However, good drilling practices need to be maintained to minimize the potential for pressure induced lost circulation. Expected Pressures • Formation pressure in the Ugnu is expected to be 8.35 ppg. • Formation pressure in the Schrader is expected to be 7.0 ppg. Pad Data Sheet • Refer to the MPS-Pad Pad Data Sheets for off-set well data. Hydrocarbons • Hydrocarbons are anticipated in the Ugnu & Schrader Bluff intervals. Faults • The wellbore will encounter one interpreted fault, the KWS_220. This is a down- to-the-west , N-S striking fault with a displacement of approximately 120'. There is uncertainty in the interpreted location of this fault plane; the P50 is expected at MP-COHO-01 Test Page 5 4/17/2007 ~ ~ -3115 TVDss, however, the fault could be encountered as early in the well as - 2885 TVDss (P10) or as late as -3241 TVDss (P90). Though this fault is interpreted to be a single fault plane, there is a possibility that it could be a zone of disruption affecting tens of MD feet of the wellbore, all within the defined zone of uncertainty. Hydrogen Sulfide • Hydrogen sulfide is not anticipated. The closest wells had <2 ppm. Anti-collision Issues • All off-set wells Pass Major Risk for this wellplan. Distance to Nearest Property • 2020' (shortest distance from BHL to MPU/PBU unit boundary) Distance to Nearest Well Within Pool • 815' from MPS-08 (MB-1 f/COHO MP-COHO-01 Test Page 6 4/17/2007 , , ~ ~ Operations Outline: Pre-Riq Operations 1. Drill and set 20" conductor casing and well cellar. 2. Install FMC landing ring on conductor. Well Summarv 1. MIRU and NU Diverter. 2. Function Test Diverter, PU 4" DP and BHA. 3. Drill 12-1/4' surface hole to 3845' MD (3505' TVD) with water base mud. 4. Run 9-5/8" surface casing and cement to surface. 5. ND diverter and NU BOPE and test as required. 6. Drill-ouUtest 9-5/8" casing with 8-1/2" bit. Drill 20'-50' of new hole and perform a FIT. 7. Drill and core the 8-1/2" hole with 10-2-10.4 ppg oil based mud/core fluid through Ugnu and Schrader sands to a final TD of 4791' MD (4402' TVD). 8. Run open-hole logs as required. 9. Condition 8-1/2" hole for 7" casing. 1 ~. Run and cement 7" casing from final well TD to -464' inside 9-5/8" casing displacing the well to seawater when bumping the plug on the liner cement job. (NOTE: A DV collar will be positioned in the 7" casing at -3381' MD to circulate out the excess cement in the 9-5/8" x 7" annulus as well as to freeze protect the OA to -2200' MD with diesel.) 1 1. RIH w/6" clean-out assembly and clean-out well to PBTD and displace well to 9.4 ppg brine to provide kill- weight fluid status and to freeze protect the well through the permafrost. 12. On TOH, do not fill the hole to drop the fluid column in the 7" to ~400 from the top of the well (-15 bbls of brine). (NOTE: The brine displacement when running 2500' of the 3-1/2" circulating string will bring the fluid level in the tubing and IA to -100' MD.) 13. Run and land circulation string (3-1/2" tubing to ~2500 MD). (NOTE; There will be -100' air gap on top of the well above the 9.4 ppg brine to eliminate freeze-back concerns.) 14. ND BOPE/NU tree and test. 15. Release rig. Post Riq• 1. USIT log 7" casing. MP-COHO-01 Test Page 7 4/17/2007 , , C:\Documents and S~ngs\stewmasd\Local Settings\Temp~ Internet Files\OLK2C\COHO Test.CL Wellhead. 11" 5K FMC Tree_ Cameron 3-1/8" SK 20", 92#, H-40, Welded Insulated Conductor at - -80' MD KOP @ 500' Max. Hole Angle = 30 deg. f/1484' - 3369' MD Drilling Mud I 9-5/8", 40#/ft., L-80 BTC -3845' MI Cemei 7" 26#/ft., L-80, BTC-M Casing (Drift ID = 6.151",cap. = 0.0383 b Freeze Protect -2200' MD -1/2", 9.2#, L-80, IBT-M Tubing t -2500' MD (Circulation String) Collar / TOC -3381' MD 3 Brine Leaend: Diesel ~ _ Cement . 9.4 pP9 Brine : Drilling Mud (>9.0 Pp9) DATE REV. BY CAMMENTS MILNE POINT UNIT 04/11/07 JGR Planned Completion MP-COHO -01 Well ore M P~~ O I I O'O ~ Orig. KB Elev. _##.#` (N##E) Orig. GL Elev. _ ##.#' ;T to Tbg. Spool = ##.#' (N##E) )` Air-Gap at Collar , ~ ~..at Shoe 4711 ` MD I 4791 ` M COMPANYDETAILS ~ RP Am~ CalculalionMethod: MinimumCurvalure ertoc System: ISCWSA Scan Me~hod: Trav Cylinder Nonh ErrorSurfacc: EIlip~ical+Casing Waming Melhod: R~les Baeed ~~ ~ ~ ~"~ '. _ c u~. °o ~ c A U ~ 7 ~ F REFERENCEINFORMATION Co~ordinatc (NB) ReCcrence: Well Centre: Plan Chopa, Truc Nonh Verlical (TVD) ReCeronce: 3830CL~3430RKB 72.fi(1 se~~~~~(vs>xece~a~~~: smi- ~o.nnN,o.~~ne~ Measuced Deplh ReCerence: 383nGL+3430RK6 72b0 Calcula~on Mcihod: Minimum Curvawre SURVEY PROGRAM Plan: Plan Chops WP 1 I(Plan Chops/Plan CHOPS) Dep~h Fm Dep~h To Survey/Plan Tool C~ea~ed By: Ede P. Halliburton Da~e: OA02007 34.3n 120(1.00 Planned: Plan Chope WP 11 V3fi CB-GYRO-SS Checked: Da~e: 12(HIAO 4790.95 Planned: Plan Chops WP I I V3fi MWD+~FR~~MS TARGET DETAILS Name TVD +N/-S +g/-W Northing Easting Shape Chops Tl 3504.60 -978.47 ]04399 5998936.00 56660424 Circle (Radius: 100) Chops 7'2 3757.60 -1035.95 1105.1 I 5998879.07 566666.05 Circlo (Radius: I50) "-' --- Start Dir 2/100' : 250' MD, 250'TVD ~~ ~ ` Start Dir 2.5/]00' : 350.02' MD, 350'TVD ~6~ End Dir : 1454.02' MD, I402.05' TVD 1000 2A Reviewed: Da~e: wELL DETAILS Namc +N/-S +p/.~y Nonhing 8 asting LatiWdc Longi Nde Slo~ PlanChops -fi5.7R -793.59 5999905.18 Sfi5552.Of1 70°24'35.681N 149°27'S8.434W N/A SECI70N DBTAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target I 3430 Q00 0.00 3430 OAO 0.00 0.00 QUO OAO 2 250.00 0.00 Q00 250.00 Q00 O.UO UAO 0.00 0.00 3 350.02 2.00 133.15 350.00 -L19 ]2~ 2A0 133.15 1.75 4 145492 29.60 133.15 1402.05 -204.79 218.46 2.50 0.00 299.44 5 3339.U2 29.60 133.15 3047.05 -841.57 89795 OAO UAO 1230.53 6 3788.07 18.38 133.15 3450.60 -966.21 1030.70 2.50 180.00 1412.77 7 3837.53 183R 133.15 3497.60 -976.SR 1042.10 Q00 O.UO 1428.38 8 3R62.53 1838 133.15 352133 -98227 ]047.84 0.00 0.00 1436.26 9 4274.19 18.38 133.15 3911.99 -1071.02 1142.52 0.00 0.00 1566.03 IU 4590.95 1838 133.15 4212.60 -113932 121537 400 0.00 1665.88 Il 4790.95 18.38 133.15 4402.40 -tIR2.44 126137 0.00 O.W 1728.93 CASING DETAILS ~.~i ~~~~~'~~~~ No. TVD MD Name Size I 3504.60 384491 9 5/8" 9.625 ~~~~~~. ~~'~~~~~ ~~~~~~~~ 2 440236 4790.90 7" '7.000 FORMATION TOP DETAILS No. TVDPath MDPath Formation I 1872.60 1995.20 BPRF 2 3538.60 3880J4 TUZC BPRF ` Start Dir 2.5/100' : 3339.02' MD, 3041.OSTVD 3 3730.60 4083.05 M87F (-Ugnu Ma) 2000 ~ i 4 3757.60 4111.50 M80T(-MBI) ~ 5 3977.60 434332 SBF2-NA ~0 ~ i 6 4007.60 4374.93 SBFI-NB ~ 7 4192.60 4569.87 TSBD-Top OA ~ 8 4192.60 4569.87 SBAS Top OB i End Dir : 3788.OP MD, 3450.6' TVD 9 4212.60 4590.95 SBAS-Base OB / i ~ i / / / 3000 ~ i I / / / / ~ i / / ~~ Chops Tl i TUZC _ i ~ ~~~ ~ ``_ _ ~ /--- 95/8„ M87F (- Ugnu Ma) ~ ' ~ ~ Chops T2 M80T(~MB]) ---- '"- 1$ SBF2-NA ------ __ _ ' --' Total Depth : 4790.95' MD, 4402.4' TVD SBF1-NB ~ ~~~ ~ ~~ TSBD-Top OA ~ ~~~ _ _ _ - , ~ Plan CHOPS i SBAS Top OB ~~ ` ' Plan Chops WP ll SBAS-Base OB 1 Vertical Section at 133.15° [800Win] 6400 7200 COMPANY DETNLS BP Amoco Calcula~ion Method: Minimum Curvawrc Enor SysWm: ISCWSA Scan Method: Trev CylindcrNorth P ror Surface: Ellipiical ~~ Caeing Waming Me~hod: Rules Based ~i ~ 300 51 c w 0 0 + r ~ 0 ~ ~ 7 0 ~ REF8R8NC51NFORMATION Co-ordinate (N/E) Reference: Well Cenve: Plan Chops, True Nonh Vertical (7'VD) Refuence: 38.3(IGL+343fIRKB 72.60 sooao~~vs)aorua~o~: sioi- ~nno~,n.ooe~ MeasmeA Depth Reference: 38.3fIGL+343URK8 72.h0 Calculation Method: Minimum Curvature SURVEY PROGRAM Plan: Pian Chops WP 11 (Plan Chope/Plan CHOPS) Dep~h Fm Dcpih To 5urvey/Plai~ Tool Created By: Erle P. Haliiburmn Da~o: 4/102U07 34.30 120[I.fNI Planned:PlanChopsWPIIV3fi CB-GYRO-SS WP,LLDETAILS ~ 12(NI.00 4790.95 Plauned: PlanChops WP I I V35 MWD~r~FR+-MS . .. ~ ~ '~~. ,... ~ ~ . Spsrry Dr~l~-ng Servic~s +N/-S *FA-W Non hing Fasting Latiwde Longimde Sbi Chops -h5.78 -793.fi9 5999905.IN Sfi5552.00 70"24'3fi.fiSIN 149°27'SN.434W ~l/A SECTION DETAILS Sec MD Ine Azi TVD +N/-S +g/_W DLe~ TFace VSec Target I 3430 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 z zso.oo o.oo o.oo zso.oo o.oo o.oo o.oo o.oo o.oo 3 350.02 2.00 133.15 350.00 -L19 1.27 2.00 133.L5 1.75 4 1454.02 29.60 133.15 I402.05 -204J9 218.46 2.50 0.00 299.44 5 3339.02 29.60 133.15 3041.05 -841.57 897J5 0.00 0.00 1230.53 6 3788A1 1838 133.15 3450.60 -966.21 1030.70 2.50 180.00 14i2.77 7 3837.53 1838 133.15 3497.60 -976.88 1042.10 0.00 0.00 142838 8 3862.53 18.38 133.15 352133 -982.27 1047.84 0.00 0.00 1436.26 9 4274.19 18.38 133.15 3911.99 -1071.02 1142.52 0.00 0.00 1566.03 10 4590.95 1838 I33.15 4212.60 -113932 121537 0.00 0.00 1665.58 i l 4790.95 1838 133.15 4402.40 -L 182.44 1261.37 0.00 0.00 1728.93 TARGET DETAILS Namc TVD +N/-S +E/-W Northing Easting Shape Chops TI 3504.60 - 978.47 1043.79 599R936.00 56660424 Circle (Radius: 100 Chops T2 375Z60 -1 035.95 1105.11 5998879.07 566666.05 Circle (Radius: ISU) FORMATION TOP DETAILS No. TVDPath MDPath Formation 1 1872.60 1995.20 BPRF 2 3538.60 3880.74 TUZC 3 3730.60 4083.05 M87F (-Ugnu Ma) 4 3757.60 4l 11.50 M80T (~MB I) S 3977.60 434332 SBF2-NA 6 4007.60 4374.93 SBFI-NB 7 4192.60 4569.87 TSBD-Top OA 8 4192.60 4569.87 SBAS Top OB 9 4212.60 4590.95 SBAS-Base OB ~ CASING DETAILS No. TVD MD Name Size I 3504.60 3844.91 9 5/8" 9.625 2 44023 6 4790.90 7" 7.000 ND, 3041.05'TVD mf. End Dir : 3788.01' MD, 3450.6' TVD i ~ i ChopsTl i Chops T2 _~ 0 600 900 Total Depth : 4790,95' MD, 4402.4' TVD ~ i~ i _ _ - - Plan CHOPS ~ `` Plan Chops WP 1 l 7" / 1500 1800 2 West(-)/East(+) [300fr/in] ~ Halliburton Com an ~ P Y BP Planning Report Coropanyc ';BP Rmaca Date: 4M2/20~7 Time: '#4:4f3:11 i Page: ' 1 ~'ie~d. !Mi)ne Foint Go-vrdirratc(N~} Reference: '' Weii: Plan COHC7-41, True htorfh ' ~ite: ' M Pt S Pad Ver#ica} ('t'VA} Reference: ' 38.~~~L+34.30FtKB 72.6. Weli: Plan COHC}-~'E ' Section (VS) Reference: ' We}I ((?.t30N,p.0(}E,133.15Azi} Wellpath: :Pl~n G~HO-(11 Survey Calc~lahon Methad: '~linimum ~urvature ' Db. SJrac[e Targets Map ' Map '', <---: Latitud~ --~ ~c~ L6ngit~tde --~' ' Name ' ' Description 1'YI? +NI-S '+E/-W N~rrthing ' Easting ', I3cg ;Min Se~ I?eg Min ' Sec ~ip. ' Dir: ft' ' ft fl I ft ' ft Chops T1 3504.60 -978.47 1043.79 5998936.00 566604.24 70 24 27.057 N 149 27 27.844 W -Plan hit target Chops Poly1 3504.60 -973.42 1038.60 5998941.00 566599.00 70 24 27.107 N 149 27 27.997 W -Circle (Radius: 100) -Plan out by 7.24 at 3504.60 -978.47 1043.79 5998936.00 566604.24 70 24 27.057 N 149 27 27.844 W Chops T2 3757.60 -1035.95 1105.11 5998879.07 566666.05 70 24 26.492 N 149 27 26.048 W -Plan hit target Chops Poly2 3757.60 -1032.99 1102.08 5998882.00 566663.00 70 24 26.521 N 149 27 26.136 W -Circle (Radius: 150) -Plan out by 4.23 at 3757.60 -1035.95 1105.10 5998879.07 566666.05 70 24 26.492 N 149 27 26.048 W Chops T3 4402.60 -1182.41 1261.79 5998734.00 566824.00 70 24 25.051 N 149 27 21.456 W -Plan hit target Plan Section Information ' MD Inct i Azim ', TV~} +Nl-S +El-W ULS ' Buitd Turn TFO Target ft deg ', deg ' ft ft' ft tl~gl144ft degtitl4ft deg{100fr deg 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 0.00 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 0.00 0.00 350.02 2.00 133.15 350.00 -1.19 1.27 2.00 2.00 0.00 133.15 1454.02 29.60 133.15 1402.05 -204.79 218.46 2.50 2.50 0.00 0.00 3339.02 29.60 133.15 3041.05 -841.57 897.75 0.00 0.00 0.00 0.00 3788.01 18.38 133.15 3450.60 -966.21 1030.70 2.50 -2.50 0.00 180.00 3837.53 18.38 133.15 3497.60 -976.88 1042.10 0.00 0.00 0.00 0.00 3862.53 18.38 133.15 3521.33 -982.27 1047.84 0.00 0.00 0.00 0.00 4274.19 18.38 133.15 3911.99 -1071.02 1142.52 0.00 0.00 0.00 0.00 4590.95 18.38 133.15 4212.60 -1139.32 1215.37 0.00 0.00 0.00 0.00 4790.95 18.38 133.15 4402.40 -1182.44 1261.37 0.00 0.00 0.00 0.00 Plan: Plan COHO-01 WP 11 Date Composed: 2/15/2007 Version: 41 Princ;pal: Yes T;ed-to: From Well Ref. Point Field: Milne Point North Slope UN~TED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Site: M Pt S Pad Site Position: Northing: 5999978.00 ft Latitude: 70 24 37.329 N From: Map Easting: 566345.00 ft Longitude: 149 27 35.171 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.51 deg Well: Plan COHO-01 Slot Name: formerly CHOPS Well Position: +N/-S -65.78 ft Northing: 5999905.18 ft Latitude: 70 24 36.681 N +E/-W -793.69 ft Easting : 565552.00 ft Longitude: 149 27 58.434 W Position Uncertainty: 0.00 ft Wellpath: Plan COHO-01 Drilled From: Well Ref. Point formerly CHOPS Tie-on Depth: 34.30 ft Current Datum: 38.30GL+34.30RK6 Height 72.60 ft Above System Datum: Mean Sea Level Magnefic Data: 12/4/2006 Declination: 23.80 deg Field Strength: 57627 nT Mag Dip Angle: 80.92 deg Vertical Section: Depth From (TVD) +N/-S +E/-W DirectioR ft ft ft deg 34.30 0.00 0.00 133.15 • Halliburton Com an ~ p Y BP Planning Report Survey 34.30 0.00 0.00 -38.30 0.00 0.00 0.00 0.00 0.00 5999905.18 565552.00 CB-GYR 100.00 0.00 0.00 27.40 0.00 0.00 0.00 0.00 0.00 5999905.18 565552.00 CB-GYR 200.00 0.00 0.00 127.40 0.00 0.00 0.00 0.00 0.00 5999905.18 565552.00 CB-GYR 250.OQ 0.00 0.00 177.40 0.00 0.00 0.00 0.00 0.00 5999905.18 565552.00 CB-GYR 300.00 1.00 133.15 227.40 -0.30 0.32 0.44 2.00 0.00 5999904.88 565552.32 CB-GYR 350.02 2.00 133.15 277.40 -1.19 1.27 1.75 2.00 0.00 5999904.00 565553.28 CB-GYR 400.00 3.25 133.15 327.33 -2.76 2.94 4.03 2.50 0.00 5999902.45 565554.97 CB-GYR 500.00 5.75 133.15 427.01 -8.12 8.67 11.88 2.50 0.00 5999897.13 565560.74 CB-GYR 600.00 8.25 133.15 526.26 -16.46 17.56 24.06 2.50 0.00 5999888.88 565569.70 CB-GYR 700.00 10.75 133.15 624.88 -27.74 29.60 40.57 2.50 0.00 5999877.70 565581.84 CB-GYR 800.00 13.25 133.15 722.69 -41.96 44.76 61.35 2.50 0.00 5999863.62 565597.12 CB-GYR 900.00 15.75 133.15 819.49 -59.08 63.03 86.39 2.50 0.00 5999846.66 565615.54 CB-GYR 1000.00 18.25 133.15 915.12 -79.08 84.36 115.62 2.50 0.00 5999826.85 565637.04 CB-GYR 1100.00 20.75 133.15 1009.37 -101.90 108.71 149.00 2.50 0.00 5999804.24 565661.59 CB-GYR 1200.00 23.25 133.15 1102.08 -127.52 136.03 186.46 2.50 0.00 5999778.87 565689.13 MWD+IF 1300.00 25.75 133.15 1193.07 -155.88 166.29 227.92 2.50 0.00 5999750.78 565719.63 MWD+IF 1400.00 28.25 133.15 1282.17 -186.93 199.40 273.32 2.50 0.00 5999720.03 565753.02 MWD+IF 1454.02 29.60 133.15 1329.45 -204.79 218.46 299.44 2.50 0.00 5999702.33 565772.23 MWD+IF 1500.00 29.60 133.15 1369.43 -220.33 235.03 322.16 0.00 0.00 5999686.95 565788.94 MWD+IF 1600:00 29.60 133.15 1456.38 -254.11 271.07 371.55 0.00 0.00 5999653.49 565825.26 MWD+IF 1700.00 29.60 133.15 1543.33 -287.89 307.11 420.94 0.00 0.00 5999620.03 565861.59 MWD+IF 1800.00 29.60 133.15 1630.28 -321.67 343.14 470.34 0.00 0.00 5999586.56 565897.92 MWD+IF 1900.00 29.60 133.15 1717.22 -355.45 379.18 519.73 0.00 0.00 5999553.10 565934.25 MWD+IF 2000.00 29.60 133.15 1804.17 -389.23 415.22 569.13 0.00 0.00 5999519.64 565970.58 MWD+IF 2100.00 29.60 133.15 1891.12 -423.01 451.25 618.52 0.00 0.00 5999486.18 566006.90 MWD+IF 2200.00 29.60 133.15 1978.07 -456.79 487.29 667.92 0.00 0.00 5999452.72 566043.23 MWD+IF 2300.00 29.60 133.15 2065.02 -490.58 523.32 717.31 0.00 0.00 5999419.26 566079.56 MWD+IF 2400.00 29.60 133.15 2151.97 -524.36 559.36 766.70 0.00 0.00 5999385.80 566115.89 MWD+IF 2500.00 29.60 133.15 2238.92 -558.14 595.40 816.10 0.00 0.00 5999352.34 566152.22 MWD+IF 2600.00 29.60 133.15 2325.87 -591.92 631.43 865.49 0.00 0.00 5999318.88 566188.54 MWD+IF 2700.00 29.60 133.15 2412.82 -625.70 667.47 914.89 0.00 0.00 5999285.42 566224.87 MWD+IF 2800.00 29.60 133.15 2499.77 -659.48 703.51 964.28 0.00 0.00 5999251.96 566261.20 MWD+IF 2900.00 29.60 133.15 2586.72 -693.26 739.54 1013.67 0.00 0.00 5999218.50 566297.53 MWD+IF 3000.00 29.60 133.15 2673.67 -727.04 775.58 1063.07 0.00 0.00 5999185.04 566333.86 MWD+IF 3100.00 29.60 133.15 2760.62 -760.83 811.62 1112.46 0.00 0.00 5999151.58 566370.18 MWD+IF 3200.00 29.60 133.15 2847.57 -794.61 847.65 1161.86 0.00 0.00 5999118.12 566406.51 MWD+IF 3300.00 29.60 133.15 2934.52 -828.39 883.69 1211.25 0.00 0.00 5999084.66 566442.84 MWD+IF 3339.02 29.60 133.'!5 2968.45 -841.57 897.75 1230.53 0.00 0.00 5999071.60 566457.01 MWD+IF 3400.00 28.08 133.15 3021.86 -861.68 919.21 1259.94 2.50 180.00 5999051.68 566478.65 MWD+IF 3500.00 25.58 133.15 3111.09 -892.55 952.13 1305.06 2.50 180.00 5999021.11 566511.83 MWD+IF 3600.00 23.08 133.15 3202.21 -920.71 982.18 1346.25 2.50 180.00 5998993.21 566542.13 MWD+IF 3700.00 20.58 133.15 3295.03 -946.14 1009.30 1383.42 2.50 180.00 5998968.03 566569.47 MWD+IF 3788.01 18.38 133.15 3378.00 -966.21 1030.70 1412.77 2.50 180.00 5998948.15 566591.05 MWD+IF 3800.00 18.38 133.15 3389.38 -968.79 1033.46 1416.55 0.00 0.00 5998945.59 566593.83 MWD+IF 3837.53 18.38 133.15 3425.00 -976.88 1042.10 1428.38 0.00 0.00 5998937.57 566602.53 MWD+IF 3844.91 18.38 133.15 3432.00 -978.47 1043.79 1430.70 0.00 0.00 5998936.00 566604.24 Chops T 3862.53 18.38 133.15 3448.73 -982.27 1047.84 1436.26 0.00 0.00 5998932.23 566608.33 MWD+IF 3900.00 18.38 133.15 3484.28 -990.35 1056.46 1448.07 0.00 0.00 5998924.23 566617.01 MWD+IF 4000.00 18.38 133.15 3579.18 -1011.91 1079.46 1479.59 0.00 0.00 5998902.88 566640.20 MWD+IF 4100.00 18.38 133.15 3674.08 -1033.47 1102.46 1511.12 0.00 0.00 5998881.52 566663.38 MWD+IF 4111.50 18.38 133.15 3685.00 -1035.95 1105.10 1514.74 0.00 0.00 5998879.07 566666.05 Chops T 4200.00 18.38 133.15 3768.99 -1055.03 1125.46 1542.64 0.00 0.00 5998860.17 566686.57 MWD+IF 4274.19 18.38 133.15 3839.39 -1071.02 1142.52 1566.03 0.00 0.00 5998844.33 566703.77 MWD+IF Tool S S S S S • Halliburton Com an ~ p Y BP Planning Report sarvey 4300.00 18.38 133.15 3863.89 -1076.59 1148.46 1574.17 0.00 0.00 5998838.81 566709.75 MWD+IF 4400.00 18.38 133.15 3958.79 -1098.15 1171.46 1605.69 0.00 0.00 5998817.46 566732.94 MWD+IF 4500.00 18.38 133.15 4053.69 -1119.71 1194.45 1637.21 0.00 0.00 5998796.10 566756.12 MWD+IF 4590.95 18.38 133.15 4140.00 -1139.32 1215.37 1665.88 0.00 0.00 5998776.68 566777.21 MWD+IF 4600.00 18.38 133.15 4148.59 -1141.27 1217.45 1668.74 0.00 0.00 5998774.75 566779.31 MWD+IF 4700.00 18.38 133.15 4243.49 -1162.83 1240.45 1700.26 0.00 0.00 5998753.39 566802.49 MWD+IF 4790.90 18.38 133.15 4329.76 -1182.42 1261.36 1728.92 0.00 0.00 5998733.98 566823.57 7" 4790.95 18.38 133.15 4329.80 -1182.44 1261.37 1728.93 0.00 0.00 5998733.97 566823.58 MWD+IF Tool MS MS MS MS ~ • \Ul{2Y ~lOG4M f~ Orpi. f~7.P1~ T~ol I elseeel~<l~ryMUVJS ctcn o-3f I 1MM 1'flAd PI~Alf~[ly~MlIIV)~ MWDH II.YS Ftm f daar ToMD J~ ~ 2N~ 2!~ - «p a_ •. : . . . MN - 6W nn'tl_f. 60~ ~ _ ~ B00 -_- 1~ . r. .~~rt.a ,~ wRF IMM - ISOB ..., . .. 159~ ZIIUB ]~ «a..e ~f ~ ~+a F Fram Cd Te]0 308~ ~ LMIB rlt~G '~°m` em-vJ = l~ :f0 3lB~ J00~ ~ JOOB - IS110 t~i. om n.. s+.. 2f0 - tl0 ~ - ~ 35U~ - i011U ~ - ~ MHM tl00 1000 - ~fOU i1d ,VNy ._ - ~000 .- <i1M LIW ~ 1f00 ~ iM ~ 6~.011 ~rypy ~~ ~ 100U I ~ ~N ~ _ ~~ 0 1.M0 ~ - lJ00 i Mq0 tlp ' ~~ ~ • / IM1~1 J u00 - fSOo ~~00 ~ 6!00 1 `. ~ 61110 - !tt0 1100 - BOOo '. ,~ .~ 8000 AtW ~ IOWU ~ ~ I I O 10 i A :v . • • ua v .p Tm.IW~ c~lieds nmu~6 ~iiw.~l ~d.Rl ~• ~~~ b Cme s.pww~lOM1b~ N2Il,plTApS va~.~ .W'E ~P/.W \uMq iwA I.aeW 1~{s4 Ya N~(]eN 4l~ .~W49 fWOWf.I[ M~...m Q~A' Iv 1~'ETLdW W~ . ..,. r....~crw.~wma.v~lltil..cr..uc.r.~e~.~l~ru~.l ! • Halliburton Company Anticollision Report Compa~ry: ~ ~BPAmoca ~ Date: 4/70/1007 . 1Yma 08::25:05 ~ ~ . Page: . 1 ~. Fkld: ~ MAne Pdnt ~ . . . . . . . . . . . Reference Slte: M Pt S Ped ~ . . Co-ordiaate(NE) ReCere~e: ~~.. Well: Plen Chaps.. True North ~~ . Refe~ence Wetl: Plan Chops Verlkel (IVD) Referenu; 38.30GL+34.30RK8 72.6 Refa~ence Wdlpam: Plan CHOPS ~ ~ ~ ~ . ~ ~Db: ~acle ~ GIABAL SCAPI APPLIED: All wellpatAs wltdia 2004 100/10~of ~erena Refaeoiz: Prinapal Plan & PLANNED PROGRAM Interpolatlon Melhod: MD IntervW: 25.00 R Error Model: ISCWSA Eliq>se Depfh Rangr. 34.30 to 4790.95 ft Scan MMAod: Trev Cylinder North Maatmum Radins: 675.66 fl Error Surtace: Ellipse • Cesing Sw'vey A'ogra~0 for Deflnitive Wdipath Dste: 12/42006 VWdsfed: No Version: 2 Planned FYom To Survey Todcode Tool Name R R 34.30 1250.00 Poenned: Plan Chaps WP 11 V36 C&GYRO-SS Camere based gyro single shots 1250.00 4272.00 Plenned: Plan Chaps WP 11 V36 MWD+IFR+MS MWD + IFR ~ MuRi Stadan 4272.00 4790.95 Plenned: Poen Chops WP 11 V36 C&GYR0.SS Camera based gyro single shots Casing Polnts hID ~ T'VD Dlamder .~ }~k31u. Nsou . . . . . . . ~ . R ~ ft ~ in . in ~ ~~ ~ ~ 3844.91 3504.60 9.625 12.250 9 5/8" 4790.90 4402.36 7.000 8.500 7" Summary c------ Oftset Wellpath ----- > Retertn~e ~Rset . Ctr-Ctr 1~Go ~ Albwsble ~ .~ Site Wdl ~ Wellpath MD MD IMskarce Area Devlatian Wunitg R R ft ft E M Pt S Ped MPS05 MPSOS V2 46:i4.19 7200.00 171.49 68.13 103.36 Pass: Mejor RisK M Pt S Ped MPS05 MPS05Lt V2 4583.42 7175.00 210.14 69.12 141.02 Pess: Meja Ri~c M Pt S Ped MPSO6 MPSO6 V11 1833.71 1850.00 226.64 32.86 193.78 Pass: Mejw Risk M Pt S Ped MPS08 MPS08 V10 1752.29 1775.00 113.92 31.90 82:02 Pess: Mejor Risk M Pt S Pad MPS08 MPS08P81 V9 1752.29 1775.00 113.92 31.90 82.02 Pess: Mejor Risk M P[ S Pad MPS-09 MPS09 VB 2083.80 1975.00 339.18 45.47 293.71 Pass: Mejor Risk M Pt S Pad MPSt 1 MPSt 1 VS 2354.36 2275.00 282.56 51.40 231.17 Pass: Maja Risk M Pt S Pad MPS12 MPS12 VS 1277.70 1250.00 320.22 30.26 289.96 Poss: Major Risk M Pt S Pad MPS12 MPS12L1 V2 1277.70 1250.00 320.72 30.00 290.22 Pess: Major Risk M Pt S Ped MPS12 MPS12P81 V2 1277.70 1250.W 320.22 30.21 290.01 Pess: Major Risk M Pt S Pad MPS13 MPS13 VT 7557.63 1550.00 131.08 30.54 100.54 Pass: Major Risk M Pt S Ped MPS14 MPS14 V6 1250.08 1275.00 124.81 27.96 96.85 Pess: Major Risk M PI S Pad MPS15 MPS15 V7 1173.73 1150.00 29727 24.60 272.67 Pass: Mejor Risk M Pt S Ped MPS15 Plan MPS75A VO Plen: 1173.73 1150.00 297.27 24.66 272.61 Pess: Mejar Risk M Pt S Ped MPS16 MPS16 VB 897.87 875.00 296.42 17.14 27928 Pass: Mejor Risk M Pt S Ped MPS17 MPS17 V8 1192.44 1175.00 259.41 24.86 234.55 Pess: Mejor Risk M Pt S Pad MPS77 MPS-17L1 VZ 1192.44 1175.00 259.41 24.75 234.65 Pass: Mejar Risk M Pt S Ped MPS18 MPSt 8 V9 665.67 650.00 287.19 14.33 272.86 Pass: Majw Risk M Pt S Ped MPStB MP&18P81 V10 665.67 650.00 287.19 14.48 272.71 Pass: Mejw Risk M Pt S Ped MPS-18 plen MPS18A V1 Plen: 665.67 650.00 287.19 14.39 272.80 Pess: Meja Risk M Pt S Pad MPS19 MP&19 V70 793.11 775.00 257.54 15.08 242.46 Pess: Major Risk M Pt S Pad MPSt 9 MPS19A V4 793.11 775.00 257.54 14.95 242.59 Pess: Meja Risk M PI S Pad MPS19 MP&19AL1 ~ 793.11 775.00 257.54 14.95 242.59 Pass: Mejw Risk M Pt S Pad MPS19 MPS19AP81 V2 793.11 775.00 257.54 15.16 242.37 Pass: Maja Risk M Pt S Aad MPS20 MPS20 V7 960.96 950.00 220.89 19.44 201.45 Pess: Major Risk M Pt S Pa0 MPS21 MPS21 V17 732.99 725.00 724.42 73.8~ 210.55 Pass: Major Risk M Pl S Ped MPS22 MPS22 V8 1097.04 1700.00 122.14 22.41 99.73 Pess: Mejor Risk M Pt S Pad MPS23 MPS23 V12 1034.45 1025.00 178.52 20.70 157.82 Pess: Major Risk M Pt S Ped MPS23 MPS23L1 V2 1034.45 1025.00 178.52 20.68 157.85 Pass: Maja Risk M Pt S Ped MPS24 MPS24 V3 952.79 949.91 162.63 18.97 143.66 Pess: Mejor Risk M Pt S Ped MPS24 MPS24PB1 V77 952.79 949.91 162.q 19.25 143.38 Pess: Mejor Risk M Pt S Pad MPS24 MPS24P82 V5 952.79 949.91 162.63 19.21 143.42 Pass: Major Risk M Pt S Ped MPS25 MPS-25 V3 756.39 750.00 167.95 13.55 154.40 Pass: Mejw Risk M Pt S Pad MPS25 MPS25L1 V10 756.39 750.00 167.95 13.45 154.50 Pass: Mejor Risk M Pt S Pad MPS26 MP&26 V6 1096.55 1100.00 32.64 Y2.46 10.18 Pass: Mejor Risk M Pt S Pad MPS27 MPS27 V9 652.01 850.00 131.69 15.05 116.64 Pess: Maja Risk M Pt S Pad MPS27 MPS-27L7 V7 852.01 850.00 131.69 14.94 17fi.75 Pess: Mejor Risk M Pt S Pad MPS27 MPS27P81 V2 852.01 850.00 131.69 15.05 116.64 Pass: Maja Risk M Pt S Pad MPS28 MPS-28 VS 848.68 850.00 115.86 16.17 99.68 Pess: Meja Risk M Pt S Ped MPS28 MPS28PB1 V6 848.68 850.00 115.86 16.17 99.68 Pess: Majw Risk M Pt S Ped MPS28 MPS28PB2 VS 848.68 850.00 115.86 16.17 99.68 Pess: AAajw Risk M Pt S Pad MPS29 MPS29 V8 650.05 650.00 11123 12.19 99.04 Pass: Major Risk ~~ ~ i Halliburton Company Anticollision Report c~~y: aanmoco n.~: anorzoo~ r~« oa;ze:os r~: z Fkld: Mine Pdnt Reterena Site: M Pt S Pad Co ordiorte[NE) Rekrecee: Well: Plen Chops; True Narth Reference Wdl: Plan Chops Ve~iksl(7'VD) Refereaee: 38.30GL+3q.30RK8 ~ 72.6 Referenix We11qM: Plan CHOPS. ~ . . ~ ~ ~ Db: Qrade . Summay <------- -- Offxt WetlpatM -------> Rete~cnae O(fse- CYr-CYr lVaGo ~ Albwabk ~ ~~ . Sife Well ~ Welipath~ MID ~ NID~ qslance Area ~ ~ Devlatbn~ Wuning ~ . . ~ ~ . R ~ ft R . ft . E . ~ M Pt S Ped MPS29 MPS29Lt V6 650.05 650.00 111.23 12.06 99.17 Pess: Maja Risk M Pt S Pad MPS30 MPS30 V11 776.89 775.00 85.17 15.36 69.82 Pess: Majar Risk M. Pt S Pad MPS37 MPS31 V8 848.68 850.00 58.31 15.74 42.57 Pess: Maja Risk M Pt S Ped MPS32 MPS32 VS 600.63 600.00 72.00 12.96 59.03 Pess: Majw Risk M Pt S Ped MPS33 MPS-33 V11 700.70 700.00 53.83 12.87 40.96 Pess: Mejar Risk M Pt S Ped MPS33 MPS33A V7 700.70 700.00 53.83 12.87 40.96 Pass: Major Risk M Pt S Pad MPS33 RIG MPS33A V1 700.70 700.00 53.86 11.66 4220 Pess: Meja Risk M Pt S Pad MPS34 MPS34 V9 524.49 525.00 39.31 10.09 29.22 Pass: Mejw Risk M Pt S Ped MPS34 MPS-34L7 U7 524.49 525.00 39.31 10.05 29.26 Pass: Me~a Risk M Pt S Pad MPS34 MPS34L2 V9 524.49 525.00 38.31 9.94 29.37 Aass: Maja Risk M Pt S Ped MPS35 MPS35 V77 474.54 475.00 19.31 10.29 9.02 Pass: Majw Risk M Pt S Pad MPS35 MPS35PB1 Vt6 474.54 475.00 19.31 10.44 8.87 Pess: Maja Risk M Pt S Ped MPS35 MPS35PB2 V16 474.54 475.00 19.31 10.29 9.02 Pass: Mejor Risk M Pt S Pad Ren MPS38 Plen MPS39 V4 Plen: M 324.62 325.00 28.73 7.87 20.86 Pess: Mejor RisK M Pt S Ped Plen MPS40 Fem V1 Plen : Fem wp0 299.62 300.00 43.47 726 36.20 Pess: Mejw Risk M Pt S Pad plan MPS41 Mary Jeen VO Plan: Mar 324.21 325.00 58.87 6.34 52.53 Pass: Major Risk Slte: M Pt S Ped Wdl: MPS-OS RukAssig~xd: MajaRisk Wdlpath: MPS05 VZ tnter-Stte Error: 0.00 ft ~ Refereace ORset Semi-Major Asis CYr-Clr No-Co Allowable ~ MD TVD MD TVD Ref Olfset TFO+AZI TF0.H3 CaslnQlH~Islmce Mea. Devlatbn Warnin~ ~ E~ ft fl ft ft R deg deg ~ in ft ft ft~ ~ 35.30 33.30 33.30 33.30 0.00 0.00 75.59 75.59 7.625 483.19 0.85 482.34 Pess 50.00 50.00 50.00 50.00 0.04 0.01 75.59 75.59 7.625 483.19 1.12 482.07 Pass 75.00 75.00 75.00 75.00 0.09 0.02 75.58 75.58 7.625 483.21 1.59 481.62 Pess 100.00 100.00 100.00 100.00 0.15 0.04 75.57 75.57 7.625 483.24 2.05 481.19 Pess 125.00 125.00 125.00 125.00 0.24 0.06 75.56 75.56 7.625 483.29 2.64 480.65 Pess 150.00 150.00 150.W 150.00 0.32 0.09 75.54 75.54 7.625 483.34 323 480.11 Pass 175.00 175.00 175.~ 175.00 0.41 0.12 75.52 75.52 7.625 483.42 3.83 479.59 Pess 200.00 200.00 200.00 200.00 0.50 0.14 75.50 75.50 7.625 483.51 4.39 479.12 Pess 225.00 225.00 225.00 225.00 0.54 0.15 15.48 75.48 7.625 483.64 4.79 478.85 Pess 249.99 249.99 250.00 249.99 0.57 0.16 75.44 75.44 7.625 483.79 5.20 478.59 Pass 277.47 277.q7 275.00 274.99 0.58 0.18 75.39 302.24 7.625 483.88 5.53 478.35 Pess 304.92 304.92 300.00 299.99 0.59 0.19 75.30 302.15 7.625 483.86 5.87 477.99 Pass 332.36 332.35 325.00 324.98 0.60 022 75.17 302.02 7.625 483.75 6.26 477.49 Pass 360.01 359.99 350.00 349.97 0.62 0.25 75.00 301.85 7.625 483.57 6.67 476.91 Pess 388.06 388.01 375.00 374.95 0.63 0.28 74.80 301.65 7.625 483.31 7.08 47623 Pass 416.06 415.95 400.00 399.93 0.67 0.31 74.54 301.39 7.625 482.96 7.54 475.42 Pass 443.98 443.81 425.00 424.91 0.71 0.34 74.25 301.10 7.625 482.59 8.03 474.56 Pass 471.83 471.57 450.00 449.88 0.76 0.37 73.92 300.77 7.625 482.21 8.52 473.69 Pass 499.60 499.21 475.00 474.84 0.80 0.40 73.54 300.39 7.625 481.83 9.01 472.82 Pess 52727 526.72 500.00 499.78 0.85 0.43 73.12 299.97 7.625 481.51 9.52 471.99 Pass 554.82 554.08 525.00 524.71 0.91 0.46 72.64 299.49 7.625 481.29 10.02 47127 Pass 582.25 581.28 550.00 549.62 0.96 0.50 72.72 298.97 7.625 48120 10.53 470.67 Pass 609.53 608.29 575.00 574.50 1.02 0.53 71.55 298.40 7.625 481.25 11.04 470.21 Pass 636.65 635.08 600.00 599.33 1.08 0.56 70.92 297.77 7.625 481.61 11.58 470.03 Pess 663.57 661.64 625.~ 624.11 1.15 0.59 70.24 297.09 7.625 482.31 12.12 470.19 Pess 690.28 687.93 650.00 648.87 121 0.6:1 69.50 296.35 7.625 483.38 12.65 470.73 Pass 716.76 713.94 675.W 673.43 1.29 0.66 68.70 295.55 7.625 484.86 13.22 471.63 Pess 743.00 739.64 700.00 697.95 1.37 0.70 67.86 294.71 7.625 486.79 13.81 472.98 Pass 768.97 765.03 725.00 722.37 1.45 0.73 66.97 293.82 7.625 489.20 14.39 474.81 Pess 794.66 790.09 750.00 746.66 1.53 0.77 66.03 292.88 7.625 492.11 14.97 477.14 Pess 820.10 814.83 775.00 770.85 1.62 0.80 65.07 291.92 7.625 495.51 15.60 479.91 Pass 845.28 838.26 8W.00 794.92 1.72 0.84 64.09 290.94 7.625 499.38 16.24 483.14 Pass 870.22 863.37 825.00 818.87 1.82 0.87 63.10 289.95 7.625 503.75 16.88 486.87 Pass RE: MPS-Coho-O1 Tom, You are correct - the 7" will not be run as a liner. There will be no 9-5/8" x 4" DP annulus. This is carryover when we initially planned on running the 7" as a liner + tieback. Plans are instead to run a stage collar at --3381'. We'll bring cement up to the collar then flush clean above the collar. Correct cement volume should be 46 bbls: 946' of 7" x 8-I/2" + 40% ! 80' shoetrack W~ ^' ~'~ ~ ~'~ ~~ ~~3v -464' of 7" x 9-5/8" lap - bringing cement above surface casing shoe (3845' md) . Thanks. Dan -----Original Message----- From: Rose, John G (FAIRWEATHER) Sent: Friday, April 27, 2007 3:34 PM To: Thomas Maunder Cc: Hanson, Paul; Kara, Danny T Subject: RE: MPS-Coho-O1 Tom, I am now working a rotation on Nabors 2ES and I have ask either Dan or Paul to work with you on this drilling permit request. Thanks - JR -----Original Message----- From: Thomas Maunder [n~~iltc; ~o:r ~°~a~~r:_der~~acimin. st~at:.e.a~i. i:<s] Sent: Friday, April 27, 2007 2:20 PM To: Rose, John G (FAIRWEATHER) Subject: MPS-Coho-O1 John, I am reviewing the application. On the cement volume for the 7", a volume is included for 200' of 9-5/8" x 4" DP annulus. It doesn't appear that any of the 7" will be run as a liner. Could you reconcile the volume for the casing x DP annulus? Thanks in advance. Tom Maunder, PE AOGCC 1 of 1 4/30/2007 11:00 AM • • 6050000 ~ 6000000 5950000 5900000 5850000 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 400000 500000 600000 700000 800000 ~ r- - - ` 'Alaska Department of Natural Resources Land Administration System ~ • i ~ I, ~ _ . ~ ;~~~:'~~~~~~~~~~~ F~~~~ ~~~~,~~t's ~earch State Cabins . .,i..m. ,. . , r,fi,o. ~~k5&~~...,. , .ssea~. ., ., . , . ... . ~ Page 1 of 4 ~~#u~~ R~s~urcae5 ~~ 1~5 e C File Type: p-~~ = File Number: 380110 ; ~ Prin.table Case File_Summary See Township, Range, Section and Acreage? y~, w~ ~- . ~~.,. _. ;~~.:. Cs Yes ~ No http://www.dnr. state.ak.us/las/Case_Summary. cfm?FileType=ADL&FileNumber=3 80110... 4/19/2007 ' Alaska Department of Natural Resources Land Administration System Page 2 of 4 . ~ http://www.dnr. state.ak.us/las/Case_Suinmary.cfm?FileType=ADL&FileNumber=380110... 4/19/2007 " Alaska Department of Natural Resources Land Administration System Page 3 of 4 ~ i http://www.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=380110... 4/19/2007 ~ Sondra D. Stewman BP.Explo'ration AK INC. PO Box 196612 MB 7-5 Anchorage, AK 99519-6612 "Mastercard Check" ~ ss-si~ 25z 163 DATE $ ~ W ~ C7~-_.."" OLLARS First Nation~l Bank Ala: Anchorage, AK 99501 MEMO~~ l-L/~~~0 I ~: i 2 5 200060~:99 L46 2 2 7 ~ 564~~• O L6 3 ~ ~ TRAYSMIT~'AI. LE~'T~R CHECKLIST 4VELL ~iANtE /~~cS - L'OL/~O- Of PTn~ o?D~Q~S"S~O / Development Service ~xploratory Stratigraphic 1'est iYoR-ConventioQai Wett Circie 4ppropriate Letter / Paragraphs to be Inctuded ia Transmittal Getter ' CHECK i ADD-O~lS i wFiAr ~ (OPTIONS) TEXT FOR APPROVAL LETTER i ; APPLIES ~ ; ' ; ; ~ MULTI LATERAL ~ Tt:e penrtit i~ for a new welt6ore segment of existing + ~ ~ well ~ ~(If tast two digits i ~ ~ AP[ aumber in I P~~it No. , API No. ~0- are ; ' ` , ~ between 60-69) : Production should continue to be reported as a function of the ~ ~ f ~ original 4PI number stated above. : : ~ PILOT HOLE ~ ~[n accocdance with 20 AAC 2~.00~(~, all cecord;, cfata and to~s ~ f i ~ acquired for the pilot hole must be ctearly differentiated in both ~ , i ; wcll name ( Pf~ and API numbec ~ ~ ; ~ '(50- - -_) fronl records, data and logs ~ ~ I acquired for wetl ~ . i ~ SPACING I The pcrmit is approved subje~t to futl compiiance with 20 AAC ! EXCEPTION ~ 2~.0». Approva( to pecfocate and ~roduce / inicct is contingent ~ ' i ~ i I upon issuartce of a conservation order approving a spacing j ; exception. ~ I assumes the ~ i tiability of any protest to the spacing exceptioa that may occur. i i ~ ° i DRY DRCH ~ A(I dry ditch sample sets subrnitted to tt~e-Eommission must be i ; ~ i SA.tiiPLE ~ n i no greater than 30' sampie intervals &om betow the pecmafrost or ; ` ~ I from where samptes are fint caught ar~d 10' sampte inter~•ats ; ~ ~ ~ ~ ~ through tar~et zones. ~ ~ ~ ' ~ j Non-Conventional ~ Ptease note the fo(lowing special condition of this permit: ~ i production or production testing of coa! bed methane i lt ! ~~z~~ s noi a owed i ? for ~ e f weth until after (Comnany Name) has designed and ! ; ~ ~ implemented a water well testing pcagram to provide baseline data ; ~ i on water quality and quantity. 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C d ~ O N ~..~ !~ N O ~ N ~I ~ N O ~ N ~ U p ~ i: ~ ~ '~' ~ ~ \ ~ ~ ~ 0 N N °r ; ~ ~ d' ~ ~ y E :.:. .. O N . N ~ T Ur O :~.~.~.. , C L = L w Q L c~ a Q Q Q W Q ~ QQ ~ • Well History File APPENDIX Information of detailed nature that is not paKicula~ly geRnane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the fite under APPENDIX. No special effort has been made to chronologicatly organize this category of information. ~ MPS-37.tapx sperry-sun Drillin9 services LIS Scan Utility $Revision: 3 $ Lis~ib $Revision: 4 $ Mon Dec 17 13:34:31 2007 Reel Header Service name .............LISTPE Date . ...................07/12/17 Ori 9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS ~zs writing ~ibrary. Tape Header Service name .............LISTPE Date . ...................07/12/17 Origin ...................sTs Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................5T5 LIS Writing Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: 70WNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 1 Mw-000504379 A. MUNRO J. HABERTHUR MAD RUN 5 Mw-000504379 D. RICHARDSO G. BURLEY ~ Scientific Technical services ~ibrary. scientific Technical services MPS-37 50029233550000 BP Exploration Sperry Sun 17-DEC-07 MWD RUN 3 Mw-000504379 B. STEPHENS J. HABATHUR 7 12N 11E 2041 406 Page 1 (alaska), znc. MWD RUN 5 Mw-000504379 D. RICHARDSO G. BURLEY ~~--oSa 6Sfs~ . ~ ~ ~ MPS-37.tapx ELEVATION (FT FROM MSL O) KELLY BUSHING: .00 DERRICK FLOOR: 71.88 GROUND LEVEL: 38.10 # WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 15T STRING 12.250 20.000 120.0 2ND STRING 12.250 20.000 120.0 3RD STRING 8.500 9.625 3856.0 PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED, AND REFER TO BIT DEPTH. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZ- ING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), AND BIMODAL ACOUSTIC TOOL (BAT~. 3. MWD RUN 2 IS DIRECTIONAL ONLY AND NOT PRESENTED. 4. MWD RUN 3 IS DIRECTIONAL WITH DGR, EWR-4, CTN, ALD, AND BAT. DATA FROM THE INTERVAL 876~MD/839~TVD TO 2135~MD/ 1996'TVD (MWD RUN 2 INTERVAL)WAS ACQUIRED ON A MEASUREMENT AFTER DRILLING (MAD) PASS PERFORMED FOLLOWING DRILLING. ALL DATA IS PRESENTED MERGED WITH MWD DATA FROM RUN 3. 5. RUN 4 WAS A CORED INTERVAL 3864'MD/3494`TVD TO 4349'MD/ 3948~TVD. THERE IS NO MWD DATA FOR THIS INTERVAL. 6. MWD RUN 5 IS DIRECTIONAL WITH DGR, EWR-4, CTN, ALD, MAG- NETIC RESONANCE IMAGE LOGGING WHILE DRILLING (MRIL-WD), AND FORMATION TESTING WHILE DRILLING (GEOTAP FTWD). DATA IN THE RUN 4 CORED INTERVAL WAS AQUIRED ON A MAD PASS PERFORMED WHILE PULLING OUT OF THE HOLE FOLLOWING DRILING OF RUN 5. A SECOND PASS WAS THEN PERFORMED WITHOUT ROTATION TO ACQUIRE MRIL-WD DATA IN T2 MODE. THE MAD T1 DATA IS PRESENTED MERGED WITH THE DRILLED SECTION, AND MAD RESISTIVITY/GAMMA RAY/ACAL DATA IS PRESENTED WITH T2 MRIL-WD DATA PRESENTED AS MWD (ALONG WITH Page 2 . , ~ ~~ MPS-37.tapx MWD DENSITY-NEUTRON DATA). 7. MWD/MAD DATA IS DEPTH SHIFTED TO BOTH THE PDCL (DIL-GR SWS 26-JUN-07 ) AND SDCL (CNL-GR SWS 26-JUN-07) WHERE APPLICABLE. THIS SHIFTING WAS PERFORMED PER THE INSTRUCTIONS SENT BY EMAIL BY DOUG DORTCH OF SAIC ON BEHALF OF DENNIS URBAN OF BP EXPLOR- ATION (ALASKA), INC. ON 11/15/07. 8. MWD RUNS 1, 3, AND 5 REPRESENT WELL MPS-37 WITH API#: 50-029-23355-00-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 4814'MD/4385'ND. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (X-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 (EWR). TNPS = SMOOTHED THERMAL NEUTRON POROSITY-SANDSTONE LITHOLOGY. CTFA = SMOOTHED AVERAGE OF FAR NEUTRON DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR NEUTRON DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW COUNT RATE BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW COUNT RATE BIN). SNP2 = SMOOTHED PHOTOELECTRIC ABSORPTION FACTOR (LOW COUNT RATE BIN). DTCP = SMOOTHED INTERVAL TRANSIT TIME OF COMPRESSIONAL WAVE POST WELL PROCESSED TIPTOT = SMOOTHED TOTAL NMR POROSITY OBTAINED DURING T1 LOGGING MODE. (T1PT) TIPIRM = SMOOTHED IRREDUCIBLE NMR MAXIMUM POROSITY FROM T1 LOGGING. (T1PI) TIPMIC = SMOOTHED CLAY-BOUND (MICRO) NMR POROSITY FROM Tl LOGGING. (T1PM) T1LM = SMOOTHED LOG MEAN OF Tl RELAXATION TIME. T1KC = SMOOTHED T1 PERMEABILITY FROM COATES ALGORITHM. T2PTOT = SMOOTHED TOTAL NMR POROSITY OBTAINED DURING T2 LOGGING MODE. (T2PT) T2PIRM = SMOOTHED IRREDUCIBLE NMR MAXIMUM POROSITY FROM T2 LOGGING. (T2PI) T2PMIC = SMOOTHED CLAY-BOUND (MICRO) NMR POROSITY FROM T2 LOGGING. (T2PM) T2LM = SMOOTHED LOG MEAN OF T2 RELAXATION TIME. T2KC = SMOOTHED T2 PERMEABILITY FROM COATES ALGORITHM. CURVES WITH THE SUFFIX "M~~ DENOTE MAD PASS DATA. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: VARIABLE (HSI/ACAL), BIT SIZES 12.25~~, 8.5~~ Page 3 , ~ ~ MPS-37.tapx MUD WEIGHT: 9.0 - 10.5 PPG MUD SALINITY: 700-4000 PPM CHLORIDES FORMATION WATER SALINITY: 21000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE MRI-WD IRREDUCIBLE POROSITY CUTOFF: 60 MS -T1 MODE 33M5 -T2 MODE MRI-WD MICO POROSITY CUTOFF . 6 MS - T1 MODE 3MS -T2 MODE SPECTRAL BVI COEFFICIENTS: 0.031 - T1 MODE 0.062 T2 MODE COATES "C~~ COEFFICIENT = 10 T2 TE SPACINGS: TA - 4.8 MS TB - 1.2 MS @ TW = 8000 MS $ File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/12/17 Maximum Physical Record..65535 File Type. ...,........LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD ~epth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .SO00 # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH NCNT 146.5 4722.0 NPHI 146.5 4722.0 FCNT 146.5 4722.0 ~TC 147.5 3729.0 DRHO 160.0 4735.0 PEF 160.0 4735.0 RHOB 160.0 4735.0 RPM 194.0 4767.5 FET 194.0 4767.5 RPD 194.0 4767.5 RPX 194.0 4767.5 RPS 194.0 4767.5 GR 202.5 4775.0 ROP 246.5 4812.0 CALA 3749.0 4724.5 T2KC 3854.0 4408.5 T2PM 3854.0 4408.5 T2PI 3854.0 4408.5 T1LM 3854.0 4675.0 T2LM 3854.0 4408.5 T1KC 3854.0 4675.0 T1PT 3854.0 4675.0 T1PM 3854.0 4675.0 T1PI 3854.0 4675.0 T2PT 3854.0 4408.5 $ # Page 4 , ~ ~ MPS-37.tapx BASELINE CURVE FO R SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 198.5 202.0 3342.0 3346.5 3346.0 3350.5 3353.0 3358.0 3360.0 3365.0 3363.5 3368.0 3376.0 3380.5 3381.0 3385.5 3386.5 3391.0 3398.0 3402.5 3409.0 3413.5 3418.5 3423.0 3427.5 3432.0 3438.0 3442.5 3440.5 3445.0 3460.0 3464.0 3468.0 3472.0 3492.5 3496.5 3497.0 3501.0 3506.0 3510.0 3512.0 3515.0 3538.5 3542.0 3553.0 3556.0 3561.5 3565.5 3566.0 3569.5 3578.5 3582.0 3594.5 3599.0 3644.5 3647.5 3654.5 3658.5 3662.5 3666.5 3673.5 3677.5 3675.0 3679.5 3690.0 3694.5 3696.5 3701.5 3712.5 3717.5 3722.0 3727.0 3738.5 3744.0 3744.0 3749.0 3766.5 3770.0 3791.0 3795.5 3795.0 3799.5 3803.5 3808.5 3809.5 3816.5 3818.0 3824.5 3830.5 3837.0 3836.5 3843.0 3849.5 3856.0 3862.5 3869.0 3880.0 3886.5 3884.0 3890.5 3885.5 3892.0 3887.5 3894.0 3891.0 3897.5 3896.5 3903.0 3901.0 3907.5 3904.5 3911.0 3925.5 3932.0 3930.0 3936.5 3933.5 3940.0 Page 5 l, J MPS-37.tapx 3938.5 3945.0 3945.0 3951.5 3949.0 3955.5 3959.0 3965.5 3960.5 3967.0 3967.0 3973.5 3976.5 3982.5 3980.5 3986.5 3984.0 3990.0 3989.5 3995.5 3996.0 4002.0 3999.5 4005.5 4003.0 4009.0 4015.5 4020.5 4019.0 4025.5 4023.5 4030.0 4027.0 4033.5 4030.0 4036.5 4037.0 4043.5 4040.5 4047.0 4051.5 4058.0 4055.5 4062.0 4062.5 4069.0 4071.5 4077.0 4092.0 4097.5 4094.0 4100.0 4096.0 4102.0 4111.5 4117.0 4114.0 4119.5 4120.5 4126.0 4129.5 4135.0 4140.0 4145.5 4142.5 4148.0 4157.5 4162.5 4168.5 4173.0 4178.5 4183.0 4186.0 4190.5 4189.5 4194.0 4192.5 4197.0 4199.5 4204.5 4203.0 4208.0 4208.0 4213.0 4230.0 4235.0 4234.5 4239.5 4248.0 4253.0 4276.0 4281.0 4280.0 4285.0 4284.0 4289.0 4289.0 4292.5 4300.0 4303.5 4307.0 4312.5 4310.0 4315.5 4312.5 4318.0 4315.5 4321.0 4319.0 4324.5 4322.0 4327.5 4327.0 4332.5 4332.0 4337.5 4341.0 4346.5 4346.5 4352.0 4350.5 4356.0 4355.0 4360.5 4359.0 4364.0 Page 6 ~ ~ 4376.5 4381.5 4382.0 4386.5 4386.0 4390.5 4394.5 4399.5 4404.0 4408.5 4412.0 4415.5 4414.0 4417.5 4425.0 4428.0 4434.5 4438.5 4439.0 4443.0 4445.0 4449.0 4447.0 4451.0 4456.0 4460.0 4458.0 4462.0 4461.5 4464.5 4471.0 4474.0 4482.0 4485.0 4490.0 4493.0 4496.5 4499.5 4497.5 4500.5 4524.0 4526.5 4531.0 4533.0 4538.5 4540.5 4550.0 4552.0 4560.5 4562.0 4570.0 4571.5 4573.0 4574.5 4590.0 4592.0 4597.0 4599.0 4599.5 4601.5 4602,0 4604.0 4606.5 4608.5 4608.0 4610.0 4610.5 4612.5 4616.5 4618.5 4641.0 4641.0 4676.5 4676.0 4687.5 4687.0 4696.0 4696.5 4699.5 4700.0 4710.0 4711.0 4721.0 4722.0 4727.5 4728.5 4729.5 4730.5 4736.5 4737.5 4745.0 4746.0 4759.0 4762.5 4765.0 4768.5 4773.0 4775.5 4775.0 4777.5 $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 1 MWD 3 MwD 5 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record MPS-37.tapx MERGE TOP 150.0 876.0 3864.0 MERGE BASE 876.0 3864.0 4814.0 Page 7 ~ ~ ~ MPS-37.tapx Data Record Type... ..........0 Data Specification Block Type.....0 Log~ing Direction .................DOwn opt~cal log depth units...........Feet ~ata rteference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth Units. . .. .. ..... ~atum spe~ification glock sub-type...0 Name 5ervice order units size Nsam rtep 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 CA~A MwD IN 4 1 68 56 15 T1KC MWD MD 4 1 68 60 16 T1LM MWD MS 4 1 68 64 17 T1PI MWD PU 4 1 68 68 18 T1PM MWD PU 4 1 68 72 19 T1PT MWD PU 4 1 68 76 20 T2KC MWD MD 4 1 68 80 21 T2LM MWD MS 4 1 68 84 22 T2PI MWD PU 4 1 68 88 23 T2PM MWD PU 4 1 68 92 24 T2PT MWD PU 4 1 68 96 25 DTC MWD USPF 4 1 68 100 26 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 146.5 4812 2479.25 9332 146.5 4812 ROP MWD FT/H 0.19 1442.4 203.309 9131 246.5 4812 GR MwD API 12.65 149.67 72.4693 9146 202.5 4775 RPx MwD OHMM 0.19 2000 25.3994 9065 194 4767.5 RPS MwD OHMM 0.19 1899.42 35.9772 9065 194 4767.5 RPM MwD OHMM 0.23 2000 52.5756 9065 194 4767.5 RPD MwD OHMM 0.17 2000 45.5018 9065 194 4767.5 FET MwD HOUR 0.2 240.59 18.3664 9065 194 4767.5 NPHI MwD Pu-S 19.72 103.45 43.0447 8971 146.5 4722 FCNT MwD CNTS 543.09 2411.13 937.357 8971 146.5 4722 NCNT MWD CNTS 114941 205932 156429 8971 146.5 4722 RHOB MwD G/CM 1.185 2.739 2.09838 8668 160 4735 DRHO MWD G/CM -0.319 0.648 0.068683 8668 160 4735 PEF Mw~ BARN 0.08 15.02 2.22302 8676 160 4735 CALA MWD IN 8.43 9.81 8.80924 1952 3749 4724.5 T1KC MWD MD 0.0002 209.182 9.46359 1642 3854 4675 T1LM MWD MS 4.5182 89.748 19.8049 1643 3854 4675 T1PI MwD PU 9.6009 38.2965 21.2637 1642 3854 4675 T1PM MWD Pu 0.2719 17.6106 7.40143 1642 3854 4675 T1PT MWD PU 11.2658 46.5119 26.813 1643 3854 4675 Page 8 • ~ MPS-37.tapx T2KC MWD MD 0.0001 121.304 4.55016 1110 3854 4408.5 T2LM MwD MS 1.8364 29.9531 9.13405 1110 3854 4408.5 T2PI MwD PU 10.6895 33.6974 22.7941 1110 3854 4408.5 T2PM MWD Pu 2.7683 17.7134 7.89745 1110 3854 4408.5 T2PT MWD PU 12.4155 35.0751 27.3486 1110 3854 4408.5 DTC MwD USPF 50 176 130.048 7139 147.5 3729 First Reading For Entire File..........146.5 ~ast Reading For Entire File...........4812 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/12/17 Maximum Physical rtecord..65535 File Type ................LO Next File Name...........STSLIB.002 Phy5iCd1 EOF File Header Service name... .... .STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/17 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD ~epth shifted and clipped curves; DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH CALA 3897.0 RPM 3941.5 RPx 3941.5 RPS 3941.5 RPD 3941.5 FET 3941.5 GR 3948.0 RAT 3985.0 # MERGED DATA SOURCE PBU TOOL CODE MWD $ # REMARKS: MERGED MAD PASS. $ # Data Format Specification Record Data Record Type ..................0 all MAD runs merged using earliest passes. STOP DEPTH 4462.0 4506.0 4506.0 4506.0 4506.0 4506.0 4514.0 4550.0 MAD RUN NO. MAD PA55 NO. MERGE TOP MERGE BASE 5 1 3753.5 4814.5 Page 9 ~ ~ MPS-37.tapx ~ata specification Block Type.....0 Log~ing Direction .................Down optical log depth units...........Feet ~ata Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined absent value ......................-999.25 Depth units. . .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam rtep Code offset Channel DEPT FT 4 1 68 0 1 GR MAD API 4 1 68 4 2 RPX MAD OHMM 4 1 68 8 3 RPS MAD OHMM 4 1 68 12 4 RPM MAD OHMM 4 1 68 16 5 RPD MAD OHMM 4 1 68 20 6 FET MAD HOUR 4 1 68 24 7 CALA MAD IN 4 1 68 2$ 8 RAT MAD FT/H 4 1 68 32 9 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3897 4550 4223.5 1307 3897 4550 GR MAD API 23.14 111.7 61.679 1133 3948 4514 RPx MAD OHMM 1.33 2000 62.8814 1130 3941.5 4506 rtPS MAD OHMM 1.2 1980.14 53.4761 1130 3941.5 4506 RPM MAD OHMM 0.81 919.31 39.6438 1130 3941.5 4506 RPD nti4~ OHMM 0.61 1287.17 42.7297 1130 3941.5 4506 FET MAD HOUR 18.46 138.84 77.5022 982 3941.5 4506 CALA MAD IN 8.57 9.81 8.90629 1131 3897 4462 RAT MAD FT/H -297.23 198.77 -78.8596 1131 3985 4550 First rteading For Entire File..........3897 ~ast Reading For Entire File...........4550 File Trailer Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/17 Maximum Physical Record..65535 File Ty e ................LO Next Fi~e Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 Service Sub Level Name... Version Number. ........1.0.0 Date of Generation.......07/12/17 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.002 Comment Record Page 10 ! ! FILE HEADER FILE NUMBER: RAW MWD curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY MPS-37.tapx header data for each bit run in separate files. 1 .5000 VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 150.0 773.5 FCNT 150.0 773.5 NPHI 150.0 773.5 DTC 151.0 741.0 RHOB 163.5 799.5 DRHO 163.5 799.5 PEF 163.5 799.5 RPM 197.5 825.0 RPS 197.5 825.0 RPx 197.5 825.0 FET 197.5 825.0 RPD 197.5 825.0 GR 206.0 832.5 ROP 250.0 876.0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CTN aaT $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON BIMODAL ACOUSTIC 12-JUN-07 Insite 6.02 Memory 876.0 150.0 876.0 .6 7.2 TOOL NUMBER 216261 230192 140806 158417 167277 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 120.0 # BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 140.0 MUD PH: 7.0 MUD CHLORIDES (PPM): 700 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 3.800 48.0 MUD AT MAX CIRCULATING TERMPERATURE: 30.742 61.0 MUD FILTRATE AT MT: 1.620 48.0 Page 11 n u # MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSI7Y: HOLE CORRECTION (IN): # # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): MPS-37.tapx REMARKS: $ # Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Log~ing Direction .................DOwn optical log depth units...........Feet ~ata Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined ,4bsent value ......................-999.25 ~epth units. .. .. .. ..... ~atum specification Block sub-type...0 ~ 2.900 48.0 Name Service Order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWDO10 FT/H 4 1 68 4 2 GR MWDO10 API 4 1 68 8 3 RPX MWDO10 OHMM 4 1 68 12 4 RPS MWDO10 OHMM 4 1 68 16 5 RPM MWDO10 OHMM 4 1 68 20 6 RPD MWDO10 OHMM 4 1 68 24 7 FET MWDO10 HOUR 4 1 68 28 8 NPHI MWDO10 PU-S 4 1 68 32 9 FCNT MWDO10 CNTS 4 1 68 36 10 NCNT MWDO10 CNTS 4 1 68 40 11 RHOB MWDO10 G/CM 4 1 68 44 12 DRHO MWDO10 G/CM 4 1 68 48 13 PEF MWDO10 BARN 4 1 68 52 14 DTC MwD010 USPF 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 150 876 513 1453 150 876 ROP Mw~010 FT/H 4.22 386.94 188.027 1253 250 876 GR MwD010 API 23.21 121.58 61.876 1254 206 832.5 RPx MWDO10 OHMM 2.64 111.24 44.9416 1256 197.5 825 RPS MWDO10 OHMM 3.32 1262.77 97.8511 1256 197.5 825 RPM MwD010 OHMM 3.96 2000 154.174 1256 197.5 825 RPD MWDO10 OHMM 4.87 1669.36 111.698 1256 197.5 825 FET Mw~010 HOUR 0.23 6.32 1.52231 1256 197.5 825 NPHI MwD010 PU-S 23.37 90.03 47.2523 1248 150 773.5 FCNT MWDO10 CNTS 572.48 1469.44 807.302 1248 150 773.5 NCNT MWDO10 CNTS 137614 183816 149184 1248 150 773.5 RHOB MWDO10 G/CM 1.187 2.704 1.97174 1245 163.5 799.5 DRHO MWDO10 G/CM -0.055 0.648 0.16313 1245 163.5 799.5 PEF MwD010 BARN 0.36 3.15 1.77659 1245 163.5 799.5 DTC MwD010 USPF 50 126.715 89.0097 1179 151 741 Page 12 ~ • MPS-37.tapx First Reading For En~tire File..........150 Last Reading For Entire File...........876 File Trailer Service name... .......STSLIB.003 Service Sub Level Name... version Number.. ........1.0.0 Date of Generation.......07/12/17 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 wumber. ........1.0.0 Date of Generation.......07/12/17 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DTC 643.0 3734.0 NCNT 774.0 3760.5 FCNT 774.0 3760.5 NPHI 774.0 3760.5 DRHO 800.0 3777.0 PEF 800.0 3777.0 RHOB 800.0 3777.0 FET 825.5 3811.0 RPx 825.5 3811.0 RPM 825.5 3811.0 RPD 825.5 3811.0 RPS 825.5 3811.0 GR 833.0 3819.5 ROP 2135.5 3864.0 $ # LOG HEADER DATA DATE LOGGED: 15-]UN-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 3864.0 TOP LOG INTERVAL (FT): 876.0 BOTTOM LOG INTERVAL (FT): 3864.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG Page 13 ~ • MPS-37.tapx MINIMUM ANGLE: 21,$ MAXIMUM ANGLE: 34.0 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216261 EWR4 ELECTROMAG. RESIS. 4 230192 SLD STABILIZED L ITHO DEN 140806 CTN COMP THERMAL NEUTRON 158417 BAT BIMODAL ACOU Sl"IC 167277 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 120.0 # BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (S): 220.0 MUD PH: 7,Q MUD CHLORIDES (PPM): 700 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 8.000 48.0 MUD AT MAX CIRCULATING TERM PERATURE: 4.633 87.8 MUD FILTRATE AT MT: 4.100 48.0 MUD CAKE AT MT: 4.500 48.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... ......... .0 Data Specification Block Type.... .0 Log~ing Direction....... ....... .DOwn optical log depth units.......... .Feet Data Reference Point ............. .undefined Frame Spacing....... ........... .60 .lIN Max frames per record ............ .undefined ,4bsent value ..................... .-999.25 ~epth units. . .. .. .... . Datum Specification Block sub-typ e...0 -vame 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 NPHI MWD030 PU-5 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 Page 14 ~ ~ MPS-37.tapx NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 DTC MwD030 USPF 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 643 3864 2253.5 6443 643 3864 ROP MwD030 FT/H 2.35 500.49 178.444 3458 2135.5 3864 GR MWD030 API 12.65 149.67 76.2047 5974 833 3819.5 RPx MWD030 OHMM 0.19 69.19 16.6299 5972 825.5 3811 RPS MWD030 OHMM 0.19 212.14 23.6974 5972 825.5 3811 RPM MwD030 OHMM 0.23 1785.83 37.9029 5972 825.5 3811 RPD MWD030 OHMM 0.17 2000 34.3973 5972 825.5 3811 FET Mw~030 HOUR 0.2 126.2 11.604 5972 825.5 3811 NPHI MwD030 Pu-S 23.87 103.45 43.5108 5974 774 3760.5 FCNT MWD030 CNTS 543.09 1668.39 966.12 5974 774 3760.5 NCNT NIWD030 CNTS 118690 205932 163876 5974 774 3760.5 RHOB MwD030 G/CM 1.185 2.599 2.09475 5656 800 3777 DRHO MWD030 G/CM -0.319 0.477 0.060599 5656 800 3777 PEF MwD030 BARN 0.08 3.94 1.97055 5655 800 3777 DTC MwD030 USPF 50.7 176 136.928 6158 643 3734 First Reading For Entire File..........643 ~ast Reading For Entire File...........3864 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/17 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.......07/12/17 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 Comment rtecord FILE HEADER FILE NUMBER: 5 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH Page 15 ~ ~ MPS-37.tapx C,4~,4 3753.5 4725.5 PEF 3763.5 4736.0 GR 3820.0 4777.5 FCNT 3854.0 4723.0 RPD 3854.0 4770.5 RPx 3854.0 4770.5 RPS 3854.0 4770.5 NCNT 3854.0 4723.0 RPM 3854.0 4770.5 NPHI 3854.0 4723.0 FET 3854.0 4770.5 RHOB 3858.0 4736.0 DRHO 3858.0 4736.0 T1PT 3860.5 4674.5 T2KC 3860.5 4412.5 T2LM 3860.5 4412.5 T1PI 3860.5 4674.5 T2PM 3860.5 4412.5 T2PT 3860.5 4412.5 T1PM 3860.5 4674.5 T1LM 3860.5 4674.5 T1KC 3860.5 4674.5 T2PI 3860.5 4412.5 ROP 3864.5 4814.5 $ # LOG HEADER DATA DATE LOGGED: 25-JUN-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 4814.0 TOP LOG INTERVAL (FT): 3864.0 BOTTOM LOG INTERVAL (FT): 4814.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 20.0 MAXIMUM ANGLE: 20.5 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 111 EWR4 ELECTROMAG. RESIS. 4 66259 CTN COMP THERMAL NEUTRON 105918 ALD AZIMUTHAL LITHO-DEN 188935 MRIL MAG RESONANC E IMG WD 1393626 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): $.500 DRILLER'S CASING DEPTH (FT): 3856.0 # BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 10.50 MUD VISCOSITY (S): 83.0 MUD PH: .O MUD CHLORIDES (PPM): 4000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERAT URE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 70.0 MUD AT MAX CIRCULATING TERM PERATURE: .000 123.0 Page 16 ~ C~ MPS-37.tapx MUD FILTRATE AT MT: .000 70.0 MUD CAKE AT MT: .000 70.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # ~ata Format Specification Record ~ata Record Type... ..... .....0 Data Specification Block Type .....0 Log~ing Direction ............ .....Down optical log depth units...... .....Feet ~ata Reference Point ......... .....undefined Frame Spacing....... ....... .....60 .lIN Max frames per record ........ .....undefined Absent value ................. .....-999.25 ~epth units. . .. .. ..... ~atum Specification Block sub -type...0 Name service order units size -v sam rtep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 NPHI MWD050 PU-S 4 1 68 32 9 FCNT MWD050 CNTS 4 1 68 36 10 NCNT MWD050 CNTS 4 1 68 40 11 RHOB MWD050 G/CM 4 1 68 44 12 DRHO MWD050 G/CM 4 1 68 48 13 PEF MWD050 BARN 4 1 68 52 14 CA~A MwD050 IN 4 1 68 56 15 T1KC MwD050 MD 4 1 68 60 16 T1LM MWD050 MS 4 1 68 64 17 T1PI MWD050 PU 4 1 68 68 18 T1PM MWD050 PU 4 1 68 72 19 T1PT MWD050 PU 4 1 68 76 20 T2KC MWD050 MD 4 1 68 80 21 T2LM MWD050 MS 4 1 68 84 22 T2PI MWD050 PU 4 1 68 88 23 T2PM MWD050 PU 4 1 68 92 24 T2PT MWD050 Pu 4 1 68 96 25 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3753.5 4814.5 4284 2123 3753.5 4814.5 ROP MwD050 FT/H 0.19 327 81.3906 1901 3864.5 4814.5 GR MwD050 API 23.98 107.92 67.7336 1916 3820 4777.5 RPX MWD050 OHMM 1.47 2000 40.4243 1834 3854 4770.5 RPS MwD050 OHMM 1.38 1899.42 33.5337 1834 3854 4770.5 RPM MWD050 OHMM 0.77 1899.69 30.7559 1834 3854 4770.5 Page 17 ~ • MPS-37.tapx RPD MWD050 OHMM 0.74 2000 36.2843 1834 3854 4770.5 FET MwD050 HOUR 0.51 240.59 51.816 1834 3854 4770.5 NPHI MwD050 Pu-S 19.72 60.63 38.4457 1739 3854 4723 FCNT MWD050 CNTS 600.02 2411.13 931.972 1739 3854 4723 NCNT Mw~050 CNTS 114941 187470 136182 1739 3854 4723 RHOB MwD050 G/CM 1.86 2.739 2.19864 1757 3858 4736 DRHO MWD050 G/CM -0.073 0.192 0.0283108 1757 3858 4736 PEF MwD050 BARN 1.83 15.02 3.46435 1793 3763.5 4736 Ca~a MwD050 IN 8.41 9.81 8.80411 1768 3753.5 4725.5 T1KC MWD050 MD 0.0002 209.182 9.44843 1628 3860.5 4674.5 T1LM MWD050 MS 4.5182 89.748 19.7621 1629 3860.5 4674.5 T1PI MwD050 Pu 9.6009 38.2965 21.2775 1628 3860.5 4674.5 T1PM MWD050 Pu 0.2719 17.6106 7.42371 1628 3860.5 4674.5 T1PT MWD050 PU 11.2658 46.5119 26.8165 1629 3860.5 4674.5 T2KC MWD050 MD 0.0001 121.304 4.53948 1105 3860.5 4412.5 T2LM MwD050 MS 1.8364 29.9531 9.1128 1105 3860.5 4412.5 T2PI MwD050 Pu 10.6895 33.6974 22.8069 1105 3860.5 4412.5 T2PM MWD050 PU 2.7683 17.7134 7.92382 1105 3860.5 4412.5 T2PT MWD050 Pu 12.4155 35.0751 27.349 1105 3860.5 4412.5 First Reading For Entire File..........3753.5 ~ast Reading For Entire File...........4814.5 File Trailer Service name... .......STSLIB.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/17 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 PhySiCdl EOF File Header Service name... .......STSLIB.006 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/17 Maximum Physical rtecord..65535 File Type. ............LO Previous File Name.......STS~I6.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MAD Curves and log header data DEPTH INCREMENT: .5000 MAD RUN NUMBER: 5 MAD PASS NUMBER: 1 # FILE SUMMARY for each pass of each run in separate files. VENDOR TOOL CODE START DEPTH Ca~,4 3903. 5 RP5 3948.0 RPM 3948.0 RPD 3948.0 FET 3948.0 STOP DEPTH 4465.0 4509.0 4509.0 4509.0 4509.0 Page 18 • ~ MPS-37.tapx RPx 3948.0 4509.0 GR 3954.5 4516.5 RAT 3991.0 4552.0 $ # LOG HEADER DATA DATE LOGGED: 25-JUN-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 4814.0 TOP LOG INTERVAL (FT): 3864.0 BOTfOM LOG INTERVAL (FT): 4814.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 20.0 MAXIMUM ANGLE: 20.5 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 111 EWR4 ELECTROMAG. RESIS. 4 66259 CTN COMP THERMAL NEUTRON 105918 ALD AZIMUTHAL LITHO-DEN 188935 MRIL MAG RESONANCE IMG WD 1393626 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 3856.0 # BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 10.50 MUD VISCOSITY (5): 83.0 MUD PH: .O MUD CHLORIDES (PPM): 4000 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .000 123.0 MUD FILTRATE AT MT: .000 70.0 MUD CAKE AT MT: .000 70.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: # Data Format Specification Record ~ata ttecord Type... ..........0 ~ata Specification Block Type.....0 Log~ing Direction .................DOwn optical log depth units...........Feet ~ata Reference Point ..............undefined Frame Spacing .....................60 .lIN Page 19 s • MPS-37.tapx Max frames per record ....... ......undefin ed Absent value ... ...................-999.25 Depth units. . .. .. ..... ~atum specifica tion alock sub-type...0 -vame service order units size Nsam rtep Code offset Channel DEPT FT 4 1 68 0 1 GR MAD051 API 4 1 68 4 2 RPX MAD051 OHMM 4 1 68 8 3 RPS MAD051 OHMM 4 1 68 12 4 RPM MAD051 OHMM 4 1 68 16 5 RPD MAD051 OHMM 4 1 68 20 6 FET MAD051 HOUR 4 1 68 24 7 CALA MAD051 IN 4 1 68 28 8 R,4T MAD051 FT/H 4 1 68 32 9 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3903.5 4552 4227.75 1298 3903.5 4552 GR MAD051 API 23.14 111.7 61.6772 1125 3954.5 4516.5 RPx MAD051 OHMM 1.33 2000 62.8328 1123 3948 4509 RPS MAD051 OHMM 1.2 1980.14 53.5469 1123 3948 4509 RPM MAD051 OHMM 0.81 919.31 39.6761 1123 3948 4509 RPD MAD051 OHMM 0.61 1287.17 42.7404 1123 3948 4509 FET MAD051 HOUR 18.46 138.84 77.6892 974 3948 4509 CALA MAD051 IN 8.57 9.81 8.90701 1124 3903.5 4465 RAT MAD051 FT/H -297.23 198.77 -78.9298 1123 3991 4552 First Reading For Entire File..........3903 ~ast Reading For Entire File...........4552 File Trailer Service name... .......STSLIB.006 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/17 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/12/17 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name....,......UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date . ...................07/12/17 Ori in ...................STS Ree~ Name ................UNKNOWN scientific Technical services Page 20 ~ continuation Number......01 Next Reel Name...........UNKNOWN Comment5 .................STS LIS Physical EOF Physical EOF End Of LIS File • MPS-37.tapx writing ~ibrary. scientific Technical Services Page 21