The URL can be used to link to this page

Home My WebLink About198-130Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / / File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages.~. ,~1~', ~_~ f ~7, ~// Poor Quality Original'- Pages: [] Other- Pages: DIGITAL DATA Diskettes, No. Other, NofType OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beverly Mildred D'aretha a~Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: Is~ STATE OF ALASKA . AOKA OIL AND GAS CONSERVATION COMOSION °" ' °_ REPORT OF SUNDRY WELL OPERATIONS e t .y�_ t„' 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U Downhole Cannon Performed: Alter Casing ❑ Pull Tubing Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: SAVANT ALASKA LLC Development 0 Exploratory ❑ 198-130 3.Address: P.O. Box 112212, Anchorage, Alaska Stratigraphic❑ Service ❑ 6.API Number: 99511-2212 50-029-22899-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL-365533 B1-28 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Badami Oil Pool (Brookian) 11.Present Well Condition Summary: Total Depth measured 14,310 feet Plugs measured None feet true vertical 10,703 feet Junk measured 13950 & 14307 feet Effective Depth measured feet Baker Perm.Packer measured feet p 14 307 11 542 true vertical 1 0,701 feet true vertical 8498 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20", 91.5#, H-40 36'- 116' 36'- 116' 1,490 psi 470 psi Surface 5,409 9-5/8", 40#, L-80 35'- 5,444' 35'-4,522' 5,750 psi 3,090 psi Intermediate 12,001 7", 29#, P110 33'- 12,034' 33'-8,898' 11,220 psi 8,510 psi Production Liner 2,464 41/2", 12.6#, L-80 11,844'- 14,308' _ 8,729'- 10,702' _ 8,430 psi _ 7,500 psi Perforation depth Measured depth See Adjacent feet 13752-13772&13800-13810 13823-13833&14015-14035 True Vertical depth See Adjacent feet 10240-10256&10279-10287 10298-10306&10455-10472 Tubing(size,grade,measured and true vertical depth) 41/2 L-80 11,579' 8,527' HES 7x4%S3 Perm Tbg Packer 11,542' 8,498' Packers and SSSV(type,measured and true vertical depth) Baker 7x4'/2 ZXP Liner Hanger Packer 11,844' 8,738' HXO Nipple SCSSSV HES BBE 2,191' 2,187' 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A SCANNED Nov 1 4 2 U 13 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 0 0 Subsequent to operation: 194 1,116 0 1,107 psi 235 psi . 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run None Exploratory❑ Development 5 Service ❑ Stratigraphic ❑ Daily Report of Well Operations Attached WSR 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ 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: 313-284 Contact Erik Opstad(907-433-783)or Mary Rush(907-433-7805) Email Erik.Opstad(a SavantAlaska.com Printed Name ..,,./, rik 0• d Title Drilling &Wells Manager Signature Phone 907-433-7803 Date 28-Jun-2013 Form 10-404 R:?r d 10/2012 V1-----/' `U C C° / e✓ RBDMS JUL - 220 iginal Only - 149/40,/ • HALLIBUtrirCIN Alaska District Sales Order No.: Well: B1-28 Customer: SAVANT ALASKA, LLC Slickline Unit: 10026769 HAL Crew: MORGAN/538983, HOGAN/444526, MEE/526677 Mast Truck: 10249498 Pickup: N/A 3-3/8" DOWNWARD SHOOTING CANNON TO 11865'SLM SHOT MORGAN/538983 3.5" LIB TO 11839'SLM 2" DRIFT AND TAG TO 11839'SLM HOGAN/444526 MEE/526677 Date Time Description 06/13/13 START MIN 6:00 PRE JOB SAFETY MEETING, PERMITS 7:30 R/U .125"WIRE TS 1-1/2"X5'STEM, K-JAR, 1-1/2"X10 STEM OJ, LSS, 7:45 ADDED 8'SECTION OF LUBRICATOR 8:00 STOOD BY WHILE SMITH/SCHLUMBERGER RIGGED UP 3-3/8" DOWNWARD SHOOTING CANNON 8:50 STABBED ON WELL TOOK CONTROL 9:00 PRESSURE TESTED TO 1000 PSI TEST GOOD 9:15 RIH W/3-3/8" DOWNWARD SHOOTING CANNON W/E-FIRE HEAD TO 11865'SLM PULLED UP TO 11500'SLM SET TRIGGER AND ARMED CANNON WENT BACK DOWN TO 11865'SLM SHOT CANNON SAW SHOT ON WEIGHT INDACATOR PULLED UP AND SAT BACK DOWN AT 11839'SLM LIGHTY TAGGED AND POOH 12:45 OOH CHECKED OUT CANNON CUT OFF 150'OF WIRE AND RETIED 14:40 RIH W/3.5" LIB ON 3.48" DUMMY GUN TO 11839'SLM TAGGED AND POOH 16:30 OOH GOT BACK IMPRESSION OF CUT ON SIDE OF LIB C/O TOOLS 17:15 RIH W/2" BLIND BOX ON 3' 1-1/2'STEM 3.0"CENTRALIZER AND 2.84"CENTRALIZER TO END MIN 18:00 END OF 12 HR MIN 11839'SLM TAGGED HIT A FEW TIMES AND POOH 19:00 OOH RIGGED OFF WELL AND RIGGED DOWN END TICKE1 20:00 RIG DOWN COMPLETE END OF TICKET . 1. . • • p Customer Art Hoffman-Savant Alaska Date 29-May-2013 P Location Badami Well No B1-28 Ref.: B1-28 eFire and Smith Cannon ITEM (Length(inj O.D. I F/Neck I Weight ( (LBS) ( SL-eFire System 78.00 1.707 1 3/8 Firing Head Adapter 7.70 3.38 Ili Smith Firing Head 7.50 3.38 Smith Cannon Barrel 79.00 3.38 Overall Length(in) OAL(ft) 172.20 14.35 i 1 • • B1 -28 Drill Floor to Ground Level 55.62' Drill Floor to Tubing Hanger 29.4' OD ID Weight Length MD TVD Ground Level to Sea Level 119.5' Tree 4 1/16" 5000 PSI CIW!Wellhead 13 5/8"/10000 psi/FMC inch inch Lbs/ft ft DF DF < I 4'/", 12.6#L-80 IBT MOD Capacity= 0.0152 Bblslft 4.500 3.958 12.6 11544 11579 lirConductor,Grade=H-40 20" 19.124 91.1 80 116 116 < 4W',"HES HXO SCSSSV NIP ID=3.813" BBE throughbore ID=2.0" 4.500 3.813 2191 2187 1 < 4%"x 7"Annulus Capacity=0.0175 Bblslft 27° II I GLM#6: BTM Latch KBG-2LS - 'A"Port BK-1,Ptro=1816 psi 3047 3014 Ii I GLM#5:BTM Latch KBG-2LS - 1"DUMMY(extended packing) 4037 3765 62° Max Deviation 5100 4341 55° A ►< - 9 5/8"CSG,40#,L-80 BTC Capacity=0.0758 Bblslft 13.375 40 5410 5444 4522 ti I GLM#4:BTM Latch KBG-2LS - '4"Port BK-1,Ptro=1880.7 psi 7576 5794 50° t I I GLM#3:BTM Latch KBG-2LS-1"DUMMY 10144 7504 11 GLM#2:DKO-2 Port Size 1/4"(S/O) 11167 8218 Caution GLM [I ( Possibly Eroded GLM#1: Swell Valve Removed &BTM Latch KBG-2LS 11480 8452 1"DUMMY with extended packing Installed 10-08-12 40° 8 Baker S-3,7"x 4%"Permanent Packer 11542 8498 4 HES X-Nipple 9-CR 4.500 3.813 11548 8504 HES XN-Nipple,- Minimum Well ID=3.725" 4.500 3.725 11568 8519 WLEG(Note:may be cut;inspect wireline frequently beginning @ 700 feet 11579 8527 5. Ilik< Note:Probable CIBP debris on low side of 7"Csg.from DSC shot 06-13-2013 35° N Ilk 7"x 41/2" ZXP LNR HGR PKR 11844 8738 7"29#P110 BTC Casing Shoe. Csg.Capacity=0.0371 Bbls/ft 7.000 6.184 29 11980 12034 8895 Bottom of 4W'Solid Liner&Top of Slotted Liner Capacity= 0.0152Bbls/f 4.500 3.958" 12.6 206 12075 8928 Mutli-Lateral Junction Window: Top:12150' 35 12150 8990 d_ Bottom:12185' 12185 9018 s�C1 Leg#1: Top of Slotted Liner 578 13977 10317 12075'MD Top of Bottom of Slotted Liner 14551 10814 Slotted Liner Leg#2: Top of Slotted Liner 663 14150 10228 Mother Bore ptrq Bottom of Slotted Liner 14809 10737 Top Badami SS 12235 �� G FISH#2:Live 20-Ft,1%",Pert.Gun.Total Length 38',Lost 01-09-2000 38 13950 10401 330 ' —FISH#1: 14.5-foot Jet Cutter&Firing Head 14.5 14292 10683 PBTD 14307 10701 TD(Casing Shoe) 14310 10703 No. Rev.by Comments/Date B1-216 1 R.Berube Initial base schematic workup-08-20-12 Badami Unit 2 E.Opstad Edit GLM graphic&add various jewelry details.-08-23-2012 API No.50-029-22899-00 3 E.Opstad Edit top of slotted liner note for original wellbore.09-11-2012 PTD No.198-130 4 R.Berube Updates to 2 Oct 12 5 E.Opstad Updates to 15 Nov 12 Last Revised 06-15-2013 6 E.Opstad Updates to 15 June 13 SAVANT ALASKA Or Tit • • 7, m THE STATE Alaska 01i and Gas °ALASKA GOVERNOR SEAN PARNELL 333 West Seventh Avenue 0F ALA✓I � Anchorage, Alaska 99501 -3572 Main: 907.279.1433 Fax: 907.276.7542 Erik Opstad SCANNED JUN # 201'3 Drilling & Wells Manager Savant Alaska, LLC P.O. Box 112212 Anchorage, AK 99511 -2212 n C � 3 0 Re: Badami Field, Badami Oil Pool, B1 -28 Sundry Number: 313 -284 Dear Mr. Opstad: 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, / Ol t ' Daniel T. Seamount, Jr. Commissioner 1' DATED this day of June, 2013. Encl. t STATE OF ALASKA t.9A° ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re - enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. Downward Shooting Cannon INi i 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. SAVANT ALASKA, LLC Exploratory ❑ Development 19 • 198 -130 - 3. Address: P.O. Box 112212, Anchorage, Alaska Stratigraphic ❑ Service ❑ 6. API Number. Alaska. 99511 -2212 50 -029- 22899 -00 -00 ' 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑ B1 -28 • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL- 367011 ,4p,:- 36=5'5'55 /'?I 6,00 Badami Oil Pool (Brookian) 11. PRESENT WE 'LL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14,310 ' 10,703 14,307 10,701 CIBP @ 11,900' 13950' & 14307' Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20 ", 91.5 #, H -40 36' - 116' 36' - 116' 1,490 psi 470 psi Surface 5,409 9 -5/8 ", 40 #, L -80 35' - 5,444' 35' - 4,522' 5,750 psi 3,090 psi Intermediate 12,001 7 ", 29 #, P110 33' - 12,034' 33' - 8,898' 11,220 psi 8,510 psi Production Liner 2,464 4% ", 12.6 #, L -80 11,844' - 14,308' 8,729' - 10,702' 8,430 psi 7,500 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13752 -13772 & 13800 -13810 10240 -10256 & 10279 -10287 4%2" L -80 11,579' 13823 -13833 & 14015 -14035 10298 -10306 & 10455 -10472 Packers and SSSV Type: 7" x 4' /z" Baker S - Perm Tubing Packer Packers and SSSV MD (ft) and TVD (ft): Baker S -3 Packer 11,542' MD / 8,498' TVD 7" x 4'/2" Baker ZXP LNR HGR Packer HES HXO SCSSSV Nipple Baker ZXP Packer 11,844' MD / 8738' TVD No SCSSSV Installed 12. Attachments: Description Summary of Proposal ISI 13. Well Class after proposed work: • Detailed Operations Program El BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development in Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Tuesday, June 11 , 2013 Oil IS • Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Erik Opstad or Mary Rush Email Erik.Opstad @SavantAlaska.com Printed Name Erik Opstad Title Drilling & Wells Manager Alillw Signature -'-'11�� —� Phone: 907 - 433 -7803 Date: Wednesday, June 05, 2013 AO' , ....11/'� d iee COMMIS USE ONLY Conditions of a. al: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ RBDMS RBDMS JUN 11 201 Spacing Exception Required? Yes ❑ No E Subsequent Form Required: j Q — 1 W APPROVED BY 6 0 [ t3 Approved by: Ny, i COMMISSIONER THE COMMISSION Date: °�9 1S an ! 4 / Form 10 - 403 (Revised 10/2012) Approved;,�fpplication is valid for 12 months from the date of approval. ao L :- ile • • SAVANT • ALASKA Proposal Summary B1 -28 Downward Shooting Cannon Badami well B1 -28 has been shut -in since 2003. Under BP ownership the well had a troubled history. When shut -in, the well had TxIA communication issues, a CIBP with setting tool had been lost downhole on 09/03/2004 blocking the liner top and two attempts to set inflatable bridge plugs (IBP) apparently failed. Given this list of issues, BP secured the well on v' 04/18/2005 by installing a tubing tail plug (TTP) and back - pressure valve (BPV) to while the company considered other options. After assuming ownership of Badami, Savant reentered the well and repaired a leak in GLM #1 by initially installing a Halliburton Swell Valve and then later, a Dummy Gas Lift Valve (DGLV) to restored pressure integrity. Following a successful MITxIA that confirm well integrity had been reestablished for Savant, the two failed IBP's were slick -lined out of the well and the CIBP running tool also removed, leaving only the set CIBP body in place. Through this Application for Sundry Approvals Savant Alaska LLC seeks approval to use a Downward Shooting Cannon (DSC) to break -up the CIBP body and restore pressure communication with the formation. DSC devices have been successfully deployed on the North Slope in the past and the current situation in B1 -28 is well suited to the methodology. With success, we expect to reenter the well with Slickline to fish the DSC bullet along with any other debris that may result from this procedure, and then put the well back on production. It may also be desirable to jet the well clean using a coil tubing wash, but we intend to let well conditions determine the scope of any follow -on work that may be undertaken beyond the initial procedures outline herein. We're proposing to execute this job during the second week of June 2013. Submitted, Erik Opstad Drilling & Wells Manager • • SAVANT ALASKA WELL B1 -28 SPECIFIC PROCEDURE (Initiation by Schlumberger SAFE eFIRE* system) BACKGROUND INFORMATION Well Name: B1 -28 PTD# 198 -130 Current Status: Well was shut in July 2003. Production Rate: Prior to shut -in, 100 — 300 BOPD. DF to Tbg Hanger: 29.4 feet (SLM to MD Conversion) Tubing Size: 4'/2 ", 12.6 #, L -80, IBT -M Maximum Inclination: 62.0 at 5100' MD / 4341' TVD Minimum ID: 3.725" (XN NIP at 11,568' MD / 8,519' TVD. Latest H2S: None Work Scope: Use Smith /Schlumberger Downward Shooting Cannon to break -up a CIBP located in the 4%" liner at approximately 11,900' MD, thereby restoring pressure communication with the reservoir in B1 -28 and allow the well to be put back on production. Timing: This work is planned for June 10 through June 12 Badami Logistics: Coordinate with Art Hoffman ( Arthur .Hoffman(&savantalaska.com), Cell 448-6011 or Chris Boren ( Chris.Boren(&savantalaska.com), Cell phone 232 -0639. • SAVANT ALASKA PROCEDURE SUMMARY Prior to commencing the job, drift well with a tool string similar in dimensions to the DSC tool string and tag up on the CIBP to confirm its SLM depth and insure that there are no paraffin bridges or other obstructions in the borehole. 1. Inspect tree & flow line connections. Grease and service tree as necessary. 2. RU and PT other necessary support systems such as Flow -Back Tanks, Choke Skid, Lines, etc. 3. Review the JSA and all job related concerns and recommendations in a pre -job meeting inclusive of the Drilling & Wells Manager, Savant Companyman, Halliburton a -line crew, the Schlumberger team and Savant Facility Manager, AES Lead, Control Room representative and Badami Safety. 4. Ensure that communication protocols are well understood including phone and Harmony radio contact numbers. 5. Obtain unit work permit from the Badami Control Room. 6. Verify that all wellhead and annulus pressure gauges are working properly. 7. Verify that the SSV & SDV are in service and stroke correctly. 8. Adhere to HES Job Safety Analysis (JSA) guidelines while rigging -up and throughout the job. Should there be any safety concerns STOP to consult with other team members and the job Drilling & Wells Group (DAWG) Supervisor. 9. Ensure that Control -of -Work (COW) area barriers and signage are in place. 10. Confirm that the SCSSSV control line caps are tight per specification; there is no SCSSSV installed in B1 -28 at this time. Record the Tubing, IA & OA (TIO) pressures and note in the Well Service Report (WSR). 11. MIRU HES Slickline Unit, Boom Truck, Bleed Trailer, Air Heater, Light Plants and other Support Equipment as required for this job. 12. Pressure test lubricator to 2500 psi or 1000 pounds over maximum well head pressure whichever is greater. (Follow HES SOP for testing). • a. RU SSV remote control to 'Mine unit and test. Install fusible cap. 511e/(4- • • SAVANT ALASKA Unless otherwise detailed in italics, the following procedure is to be carried out by the SLB/ Smith Services Explosives Supervisor only. The SLB /Smith Services Supervisor will be available for the duration of the following procedure to advise or supervise other personnel involved with the operation when required: CANNON SHOT DETAILS Slickline company personnel to rig up Slickline minimum weight of Sinker Bars and 2 ( ) p Y p g P g 7/8" SAFE system hardware. Ensure that all checks have been made. ,+- kLA (2) Prepare the 3 -3/8" Downward Shooting Cannon as follows: a) Ensure that the bore of the Barrel is clean. b) Ensure that the `O' ring is assembled on the Bullet c/w holding rod and ring and insert to the required depth within the Barrel. c) Ensure that the '0' ring is assembled on the Bull Plug and insert into the end of the Barrel (if assembly is to be run into well for pre - operational BOP pressure test, tape Bull Plug in place). (3) Withdraw sufficient propellant and a black powder straw from the explosives store and take to the designated area. °2 (4) Lay down a layer of paper sheet on bench. Ensure work area clean of any grit, dust or e _ contaminant. Measure out 175 grams of propellant and pour into the 3 3/8" Power hh_arge Container. Ensure that the Power charge Container is then totally sealed. voo (5) Make a Propellant Straw and check the Schlumberger to Cannon Adaptor is undamaged and free of grit. Insert Straw into Adaptor and secure. (6) Gather any spilt Propellant and return to the propellant container. Retain the remaining propellant and soiled paper sheet to the explosives store. Ensure work area is cleaned with a water damp cloth. (7) Transfer the 3 -3/8" OD Downward Shooting Cannon to a convenient area where it can be secured vertically. (8) Take the Power charge Container to the cannon and insert into the Barrel. (9) Take the Cannon Adaptor c/w black powder straw to the cannon. Ensure that all threads are free of any grit and that the adaptor will not foul the Power charge container as it is screwed in. Assemble the Adaptor to the Barrel. • • SAVANT ALASKA (10) Prepare eFire SAFE system EFI and explosive ancillaries and attach to Slickline Assembly. (11) HES Slickline personnel will raise the slickline assembly and spot over the Downward Shooting Cannon. (12) Check that all threads and sealing faces are free of grit or contaminant with a cloth and assemble the Firing Head onto the Downward Shooting Cannon Adapter. Ensure that all connections on the Slickline assembly are made up tight. (13) Raise the Downward Shooting Cannon assembly. Lower the Cannon assembly into the well. eFire* Specialist removes safety pin from system. The Slickline Operator should zero the depth counter. (14) Run the Cannon assembly in hole to operating depth and gently_ tag the target. (15) Pick up and retag to confirm depth is correct. (16) Send SLB eFire* Arming and Firing commands. (17) Lightly tag CIBP with cannon. (18) Pull out all line stretch as advised by the Smith and SLB Specialists, standby for tool firing. (19) After firing, the Slickline Operator shall not use the Cannon to hammer on top of the target, but it may be used to gently retag the target. (20) Disarm eFire *, POOH at a maximum rate of 150 FPM. (21) Clear the wellhead of all non - essential P ersonnel. Note: On recovery from the well confirm detonation. (22) Disconnect the Cannon Adaptor from the wireline assembly. Visually confirm the tool has fired, Disconnect the Adaptor. Lay down the Barrel. • • SAVANT ALASKA In the event of a misfire, clear the area of all personnel. Remove the Power charge from the Barrel while still in the well house. Take the Power charge to the designated charge preparation area and empty the powder onto a clean paper sheet. Place the powder into its' authorized container, mark as misfired and return this powder and soiled paper to explosives container. Take the Adaptor c/w black powder straw to the designated charge preparation area. Remove the black powder straw from the adaptor, contain in its original packaging, mark as misfired and returned to the explosives magazine. Clean contaminated areas with water damp cloth. (23) Check TIO pressures and record in WSR. (24) RDMO Slickline Unit and Boom Truck a. Remove fusible cap, RD Slickline remote SSSV and SSV panel and return control to the Badami Board Operator. b. Take care to catch /cleanup any small drips generated while rigging down the lubricator. c. Pull Slickline unit and boom truck away from well house and move to an appropriate staging area. (25) Job Closeout: d. Verify with AES Well Tech and DAWG Supervisor that all valves are in the proper position, all caps and plugs are in place, and that the work area is clean and tidy. e. Once the worksite is in order, return to Control Room and have Area Operator close out the Unit Work Permit. f. Categorize & Coordinate post -job waste disposal with the Savant HSE Coordinator or ACS Environmental Specialist. g. Submit any post -job incident reports as may be required (spills, first aid, near - miss, etc.) to Savant. h. Turn job WSR in to DAWG Representative electronically in PDF format. i. Present field ticket for sign -off by Savant before leaving location. II/ 1110 B1-28 Drill Floor to Ground Level 54.8 Drill Floor to Tubing Hanger 29.4' OD ID Weight Length MD TVD Ground Level to Level 19.5 Tree 4 1/16" 5000 PSI CIW I Wellhead 13 5/8"/10000 psi /FMC inch ; inch Lbsift ft DF DF < L 41/2", 12.6# L -80 IBT MOD Capacity = 0.0152 Bbislft Conductor, Grade = H -40 4.500 3.958 12.6 11544 11579 20" 19.124 91.1 80 116 116 IC < 41/2"," HES HXO SCSSSV NIP ID = 3.813" (Note: no SSSV installed) 4.500 3.813 2191 2187 < 41/2" x 7" Annulus Capacity = 0.0175 Bbislft 27 4 _ 1 GLM #6: BTM Latch KBG -2LS - 1" DUMMY (extended packing) 3047 3014 4 1 GLM #5: BTM Latch KBG -2LS - 1" DUMMY (extended packing) 4037 3765 62° Max Deviation 5100 4341 55 A • 9 5/8" CSG, 40 #, L -80 BTC Capacity = 0.0758 Bbislft 13.375 40 5410 5444 4522 4 1 GLM #4: BTM Latch KBG -2LS - 1" DUMMY (extended packing) 7576 5794 50° L � 1 GLM #3: BTM Latch KBG -2LS - 1" DUMMY 10144 7504 1 1 1 GLM #2: DKO -2 Port Size 114" (S /0) 11167 8218 Eroded [I! Unusable GLM #1: Swell Valve Removed & BTM Latch KBG -2LS 11480 8452 /"DUMMY Installed 10 -08 -12 (MIT x IA - Passed) 40 Z Z Baker S -3 , 7" x 41/2" Permanent Packer 11542 8498 lo 1 HES X- Nipple 9 -CR 4.500 3.813 11548 8504 4 HES XN- Nipple, - Minimum Well ID = 3.725" 4.500 3.725 11568 8519 WLEG 11579 8527 ' \ < 7 ", 29 #, P110, BTC, Capacity = 0.0371 Bbls /ft 7.000 6.184 29 11980 12034 8891 35 7" x 4'/" ZXP LNR HGR PKR 11844 8738 I 010° < CIBP (set). 11900 8788 7" 29# P110 BTC Casing Shoe 12034 8898 I Bottom of 4'/" Solid Liner & Top of Slotted Liner Capacity = 0.0152Bbh 4.500 3.958" 12.6 206 12075 8928 Mutli - Lateral Junction Window: Top: 12150' 12185 9018 Leg #1: Top of Slotted Liner 35 12150 8990 Bottom: 12185' 578 13977 10317 12075' MD Top of Bottom of Slotted Liner 14551 10814 o Slotted Doer Leg #2: Top of Slotted Liner 663 14150 10228 Mother Bore ��'t� ® Bottom of Slotted Liner 14809 10737 Top Badami SS 12235 li FISH #2: Live 20 -Ft, 1' /a ", Perf. Gun. Total Length 38', Lost 01 -09 -2000 38 13950 10401 lo 33 � FISH #1: 14.5 -foot Jet Cutter & Firing Head 14.5 14292 10683 PBTD 14307 10701 TD (Casing Shoe) 14310 10703 No. Rev. by Comments /Date B1 -28 1 R. Berube Initial base schematic workup - 08 -20 -12 Badami Unit 2 E. Opstad Edit GLM graphic & add various jewelry details. - 08 -23 -2012 API No. 50-029 3 E. Opstad Edit top of slotted liner note for original wellbore. 09 -11 -2012 PTD No. 198 -1300 4 R. Berube Updates to 2 Oct 12 Last Revised 06 - - 2013 5 E. Opstad Updates to 15 Nov 12 6 E. Opstad Updates to 1 June 13 SWAMI ALASKA • 0 SERVCO P roduct Overview: Downward Shooting Cannon J t € X40* ••• , k 3 S. R .. ` 1 S ERVCO SERVCO ,.. SERVCO • Contents • General Information — Assembly Drawing — Description — Applications — Benefits and Features • Tool Specifications • Lab /Shop Test Results — Hotforge Test Centre — SERVCO Facility (Broussard, LA) • Field Test Results SERVCO • I High Pressure Firing Adapter Firing Head — Top Sub Disc Rod 4111111441 Barrel . µms General Information Drawing Bull Plug • • General Information Description A ballistic device which propels a bullet downhole to break or dislodge wellbore obstructions • Propellant or similar equivalent is fuel • Gas expansion accelerates bullet downward • Impacts target at velocities between 3,000 — 5,000 ft/s • No lateral expansion or deformation from cannon deployment SERVCO 1 • • General Information Applications • Designed to eliminate obstructions in tubing and casing — Fragmentation of broken flappers from subsurface safety valves — Unsetting of bridge plugs, allowing them to be pushed downhole — Removal of ball plugs from tubing completions • Open casing restrictions and partial realignment of parted casing • Used as an alternative where target material hardness or free rotation makes milling operations impractical SERVCO • • General Information Benefits and Features • Saves operational costs by eliminating wellbore obstructions more quickly and effectively than other costly intervention methods • Bullet has standard fishing neck • Custom designs available upon request • Can be run on slickline, e-line, coiled tubing, or drillpipe SERVCO • 0 Tool Specifications Barrel Dimensions Bullet OD (in) OD (in) ID (in) Length (ft) 1.700 1.047 10 1.000 2.157 2.000 10 1.437 2.700 1.500 10 1.937 3.375 2.750 8 2.690 4.0 — 5.5 3.000 8 2.937 4.5 — 5.5 3.500 8 3.437 5.00 — 5.75 4.000 8 3.937 5.625 4.500 8 4.437 Note: Barrel and bullet dimensions can be custom fabricated to suit individual customer requests s r� Barrel OD B arrel ID Bullet OD L_1/ —, r Barrel Length SERVCO • • Lab /Shop Test Results The Downward Shooting Cannon has been tested in a controlled environment on several occasions to ensure the customer a safe and effective operation when services are requested. Please note that SERVCO will accommodate individual customer testing to represent specific applications / needs. The testing determines if the Cannon is a practical solution for each customer prior to the operation. Previous testing highlights are as follows: • Flapper Valves — 100% shot success rate on six tests — All tests removed the flapper in a single Cannon shot • Bridge Plug — 100% shot success rate on three tests — The initial test required two shots to remove the plug, the following two successfully removed the plug in a single Cannon shot • Steel Plate — Nearly punctured a 2" 1018 Steel Plate supported by I- Beams. Plate severely deformed from a single shot. Determined that a minimum of 6.5 million lbs was generated during the test. SERVCO • • Hotforge Test Centre Date Target Description 1 Outcome Inconel 925 Flapper Valve housing submerged in water at ambient pressure. The DSC was centralized vertically on top of the 04/1996 from SSSV flapper and restrained against a concrete tower. Upon detonation, the flapper fragmented into several parts (only superficial damage was created to the housing). The DSC was centralized vertically on top of the plug and restrained against a concrete tower. The initial 5.5" Guiberson AVA shot resulted in no apparent damage to the bridge plug. The second shot allowed the plug to be pushed 09/1996 Shorty Bridge Plug down the tubing. Examination of the remains of the plug showed that the top of the mandrel had been sheared off and that tensile failure of the mandrel had occurred within the body of the plug. A number of the screws retaining the elements had sheared, thereby allowing the packer elements to retract. Valve housing submerged in water at ambient pressure. Flapper perforated prior to testing (.25" neat TRSSSV Flapper hole). The DSC was centralized vertically on top of the perforated flapper and restrained against a 11/1996 K500 Monel concrete tower. Upon detonation, the flapper fragmented into approximately 8 pieces. The same test was repeated with a flapper. No perforation was performed. Upon detonation, the flapper fragmented into approximately 12 pieces, showing perforation provided no additional benefit to the cannon shot. The DSC was centralized vertically on top of the ball valve assembly in the closed position at ambient 5" Halliburton Ball pressure and restrained against a concrete tower. Upon initiation, the upper half of the ball broke into 08/1998 Valve Pyromet 31 pieces with the lower half remaining intact. The ball has plastically deformed (squashed by the impact) resulting in expansion to the valve housing. As permanent deformation to the valve housing was an unacceptable outcome, no further shots were conducted. 7" TRSV Halliburton Two tests were performed on separate flappers. The first test resulted in the flapper being broken into 3 10/1998 Flapper Inconel 718 pieces with a single shot. The second test resulted in the flapper being broken into 6 pieces. The flapper housing sustained only minimal damage. All testing summarized in the table used a maximum of 150 grams of black powder. SERVCO • • SERVCO Facility (Broussard, LA) Test Case #1 — Halliburton 5' /2" CIBP Cannon Bullet Description I Outcome { t , 2.157" 1.437" Halliburton CIBP set in 20# casing. Plug mandrel and slips were removed in a single shot. a.r * " , x. y as r -, ; il , ., , a ' ' , Bullet Lodged in Plug Mandrel Plug Mandrel , \ ' ,..:-..--- . - . r ''':': ' '' ' ' /7. 3 SERVCO • • SERVCO Facility (Broussard, LA) Test Case #2 — Owens 1 3 /4" Magna Range Bridge Plug Cannon Bullet Description I Outcome 2.157" 1.437" Bridge plug set in 2 7/8" 95 chrome tubing. The shot dislodged the plug (pushed to the bottom of the test fixture). The plug was compressed 7.5" from original length. • Rig IRO 141-i rt SERVCO • . SERVCO Facility (Broussard LA) Test Case #3 — Halliburton 4 1/2" CP -2 TRSV Flapper Valve Cannon Bullet Description I Outcome The shot fragmented the a ' 2.700" 1.937" flapper valve and left no . damage to the SSSV. ,' New Flapper for 4 Comparison Fragmented i :it. Flapper ° * Fragments from AI t. r F ' Bottom of Piston and Seals �-). . Bullet . . -1" ,4 „ 1 e , 0 SERVCO • • SERVCO Facility (Broussard, LA) Test Case #4 — Metal Deformation Testing Cannon Bullet Description I Outcome A solid 2" 1018 steel plate supported by I -beams was shot. The plate 5.625" 4.50" deformed roughly 3.25" and the bullet nearly punctured completely through { the plate. It was determined the bullet created a minimum of 6,500,000 lb tI n �, . . . i 1 .. 1 t< ' 06;3 i SERVCO • • Field Test Results The Downward Shooting Cannon has proven successful in field testing, providing the customer with a cost - effective intervention method. Field testing highlights are as follows: • Flapper Valves — 90% shot success rates on ten field tests — Six tests removed the flapper in a single Cannon shot, three tests removed the flapper in two Cannon shots • Bridge Plug — 100% shot success rate on one field test • Packer — 100% shot success rate on one field test SERVCO • • Field Test Results Date Target Description / Outcome 4.5" TRB 8 FSR SHC Video confirmed the flapper valve was located in the horizontal position at 358ft. The flapper was 05/1997 Flapper K500 Monel fragmented with the first shot. There were no issues retrieving the Cannon. Subsequent drift run showed no damage to the completion and side pocket mandrel clear. Video confirmed the flapper valve was located in the horizontal position on the housing at 7,926ft. Successful full order detonation results and the Cannon was retrieved without problem. However 06/1997 5.5" Ocre Valve L80 Flapper 2" LIB shows that the flapper was still in position but the bullet has disappeared. A second shot not attempted. The completion was pulled at a later date; upon examination, scoring marks on the flapper and housing showed that the bullet had impacted on one side of the flapper, causing the flapper to flip over and allow the Bullet to pass through without fragmenting the flapper. Video was unable to determine orientation of flapper. First shot resulted in full detonation but did 08/1997 5.5" Halliburton SP -1 SSV not remove the flapper. Cannon was retrieve with no issues. Second shot fragmented the flapper. Flapper Inconel 925 Required slight overpull to retrieve Cannon from valve housing. Subsequent operations proved the Bullet did no damage to the well. The well was displaced with seawater /glycol mix and a camera confirmed the flapper was in a 5.5" Halliburton SP -1 SSV horizontal position. First run, surface indications showed bullet was fired full order. Upon recovery, 10/1997 Flapper Inconel 925 the Bullet was still held in the barrel. The second shot fragmented and removed the flapper successfully. Subsequent well operations showed that no unacceptable damage had been caused to the valve housing or the well. Prior to running, the flapper was determined to be slightly off horizontal at 988ft in a vertical hole. 09/1998 5.5" Halliburton SP -1 SSV The shot was fired with 150lbs on the flapper. The flapper was fragmented and subsequent well Flapper Inconel 925 operations showed that no unacceptable damage had been caused to the valve housing or the well. SERVCO • Field Test Results Date Target Description / Outcome Video was unable to determine the orientation of flapper; however, LIB run showed the flapper to be inverted Halliburton SP 01 and in a horizontal position. The assembly was run with 650 lbs weight and fragmented the flapper at 906 ft; 11/1998 SSV Flapper subsequently, a 4" gauge ring successfully passed through the flapper profile. After three broach runs to clean the seal bore, the valve was successfully locked open to allow the control line fluid path and the insert valve to be set and tested. The well was put back into production flowing at a rate of 4000 BOPD. Cannon deployed with 5001bs to tag plug at 10,080 ft. First shot - detonation observed at surface. Temporary PES Plug in 4'/" well pressure reduction noted. Second shot — same, no apparent movement of the fish. Third shot — same as 12/2001 initial two shots, observation of Cannon retrieved from well detailed that The Cannon Bull Plug was protruding Tail Pipe from the end of the Barrel. The Bullet was 5ft up inside of Barrel. Again, indentation and scoring to end and side of Bullet noted. No further Cannon runs conducted. Minimum of 350 Ibs weight bars (750 lbs BHA downhole hanging weight).Cannon successfully fired at 1,350 ft 5.5" Otis Ser 10 in contact with flapper. Subsequent camera run showed approximately 2/3 of flapper remaining with two 04/2005 TRSSSV Flapper further smaller pieces of junk on top. These smaller pieces fall down hole on application of injection flow and functioning of flow tube. The bottom of the flow tube had been bent inwards slightly. Subsequent swage runs were unsuccessful but a 2.25" drift run was successful in passing through the valve. 4'h° TRCF 4A A weight of 387 lbs was used at 2,089 ft. The shot was fired and the bullet was not seen on top of the valve. It 06/2007 Safety Valve, appeared the valve had been successfully removed. No further communication with the client. Inconel 718 Flapper Stuck in (Refer to Field Test Results — April 2011 for photos) ... A 3.375" Cannon was deployed and set down on 04/2011 Production Tubing the flapper. The Cannon was detonated and successfully fragmented the flapper. Production was resumed following the operation, confirmation given through camera footage. SERVCO • • Field Test Results Date Target Description / Outcome (Refer to Test Case #2) ...The well had a 1.750" Wide -Range Bridge Plug set in a Baker Model "D" Isolation 1 '/< Wide -Range Packer with 15' of cement on top. The cement was milled up with coiled tubing to one foot of the plug. E -line 10/2011 Bridge Plug w/ 15' was rigged up with 400 Ibs weight and a 2.157" Cannon. Detonation was observed at the surface and an of Cement increase in weight noted. The Cannon was picked up to ensure it was free. The assembly was free to slack off to 19,468' (ten feet below the original plug depth). Completions Client was trying to burn over a packer set at 8,947' for two weeks. They believed the packer was spinning 12/2011 System In- during the milling process. A 5.625" Cannon with 2 lbs black powder tagged the packer and successfully fired String Packer a shot. The packer did not move down. The Bullet was found inside the Cannon with debris around it. They were then able to go back in the hole with a mill and burn over the packer. SERVCO , . , • i 1 . Field Test Results - April 2011 Alaska — Flapper Valve i n Production Tub Date Target Description I Outcome Flapper Stuck in A 3.375" Cannon was deployed and set down on the flapper. The Cannon was detonated and 04/2011 Production Tubing successfully fragmented the flapper. Production was resumed following the operation, confirmation given through camera footage. #* l +If 3 L L 0 d co - "."," Nit4614 1401 SERVCO • • SERVCO Pipe Recovery and Specialty Services 4 Additional Questions: — Mike Crow, Manager — MCrow @slb.com SERVCO — (337) 837 -4540 81-28 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 09/03/04 Set CIBP @ 11900' 09/06/04 CTU #5, FCOI FISH CIBP ( SECURE WELL); MIRU. RIH WITH 2.5" JSN. SAT DOWN ON TOP OF FISH AT 11860' CTMD. FISH HAS NOT MOVED. JET AND SWEEP LINER TOP AND 7" CSG WITH 3 - 10 BBL FLOPRO SWEEPS. WELL CONTRIBUTING GAS AND OIL. CIRCULATE WELL AND POOH AT 80%. WELLBORE CLEANED UP AND FLUID PACKED WITH WATER. RIH WITH FISHING TOOLS WI SHROUDED G-SPEAR. SET DOWN ON LINER TOP (11853' CTM) SEVERAL TIMES. GOT IN LINER, SAT DOWN AT 11861' CTM. MADE ATTEMPTS TO LATCH FISH, ORIENTING TOOLS 45 DEGREES EACH TIME. AFTER 3RD ATTEMPT SAT DOWN 4FT DEEPER AT 11865' CTM. KEEP TRYING TO LATCH, UNABLE. POOH. MARKS ON BEVELED LIP OF SHROUD, NO INDICATION OF FISH INSIDE PAST THE BEVEL. PERFORM WEEKLY BOP TEST. MU BHA #3 (G-SPEAR WITH HYD CENTRALIZER, NO SHROUD). «<CONTINUED ON 9/7104 WSR»> 09/07104 FISH CIBP. SET IBP. (SECURE WELL) CTU #5. CONTINUED FROM 9/7104 WSR. RIH WITH G-SPEAR FISHING TOOLS (WITH HYD CENT). TAG FISH AT 11860' CTMD. MAKE NUMEROUS ATTEMPS TO LATCH WITH NO LUCK. POOH. FOUND G-SPEAR IN THE RELEASED POSITION AND DRILLING MUD IN TOOLS. RIH WITH WFD 3 3/8" IBP. SET AT 11830' CTMD. NUMEROUS OVERPULLS WHILE POOH. AT SURFACE, RECOVERED SETTING TOOL, BUT COIL KINKED FROM SETTING OF IBP. CUT 150' PIPE. RIH WITH 3.56" NOZZLE TO TAG IBP. «<CONTINUED ON 9/8/04 WSR»> 09108/04 SET IBP @ 11800' FLUIDS PUMPED BBLS 315 Diesel 474 XS Water 31 FloPro 198 XSLK Water 1018 TOTAL Page 1 RT. ELEV = 54.8' BF. ELEV = 19.5' MAX DEV. = 61 @ 5031' MD 13-3/8" 68#1ft L-80, BTC. CSG. I 4550 I ~ 4 1/2" L-80 IBT MOD 12.6#1ft Tubing Perforation Summary: 13,752' - 13,772' 13,800' - 13,810' 13,823' - 13,833' 14,015' - 14,035' 2.75" Predator @ 6 spf 4 1/2" L-80 IBT Solid Liner FISH: 20' Live Perf Gun. Overall length is 38' with 1 - 3/8" FN See details in well file. Multi-Lateral Details Hole #1 Top of Slotted Liner Bottom of Slotted Uner Hole #2 Top of Slotted Liner Bottom of Slotted Liner 13973 14551 14146 14809 DATE REV. BY COMMENTS B 1-28 Fish in Uner see Details TREE: 4-1/16"/5000 psi / CIW WELLHEAD: 13-518"/10000 psi / FMC HES HXO Safety Valve Nipple 10(3.813") Œill Gas Lift Summary Camco 1" KBG-2-LS GLM MD TVD DEV 5 4 3 2 1 4037 3710 7576 5727 10144 7442 11167 8180 11480 8403 57 48 49 42 40 Baker S-3 1115421 Permanent Packer HES X Nipple 9CR 1115481 10 (3.813") HES XN Nipple 9CR 1115681 10 (3.725") WLEG 1115791 ELMO CJ 7" X 4 1/2" Liner 1118581 Hanger Packer 7" 29#1ft P11 0 BTC CSG Shoe 1120341 Top of Slotted Uner 1120751 Multi-Lateral Junction Window 12150 - 12185 PBTD 14307 Casing Shoe 14308 BADAMI WELL B1-28 PE RMIT # 98- API # 50-029-22899 BP EXPLORATION, INC. 3-30-99 7-20-04 JTP U date Information CM/TLH Depth Corrections ~ STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION I./.J()A 7/'-- (' IU:: c 4 "U"i~ ..11. 'n.~- rJý -'J: ~1 ' "I '- /;if'"' ..' . -..'/' I~I . "IUL. '::? ,~.~ ~~n04 APPLICATION FOR SUNDRY APPROVA,L 20 MC 25.280 1. Type of Request: Abandon D Alter Casing D Change Approved Program D 2. Operator - , Suspend D Repair Well D Pull Tubing D Operation Shutdown D PerforateD waiverD Annular DisposalD Plug Perforations D Stimulate D Time Extension D OtherŒJ Perforate New Pool D Re-enter Suspended Well D Secure Well (' Plugs (md): Junk (md): None 12200 Burst Collapse top bottom top bottom 36 116 36.0 116.0 1490 470 11833 14308 8728.9 10701.0 8430 7500 33 12034 33.0 8894.4 11220 8510 35 4550 35.0 4051.0 5750 3090 Tubing Size: Tubing Grade: Tubing MD (ft): 4.5 " 12.6 # L-80 30 11580 4. Current Well Class: Name: BP Exploration (Alaska), Inc. / Development ŒJ Exploratory D StratigraphicD Service D 9. Well Name and Number: B1-28 / 10. Field/Pool(s): Badami Oil Field / Badami Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 14308 10645.4 MD TVD 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 55.62 KB 8. Property Designation: ADL-365533 11. Total Depth MD (ft): Total Depth TVD (ft): 14308 10701.0 Casing Length Size Conductor 80 Liner 2475 Production 12001 Surface 4515 Perforation Depth MD (fl): 13752 - 13772 13800 - 13810 13823 - 13833 14015 - 14035 Packers and SSSV Type: 4-1/2" Baker S-3 Perm Packer 4-1/2" Baker Liner Hanger Packer 20" 91.5# H-40 4-1/2" 12.6# L-80 7" 29# P-11 0 13-5/8" 68# L-80 Perforation Depth TVD (ft): 10239.9 10256.2 10279 10287.2 10297.8 10306.0 10455.5 10472.1 Packers and SSSV MD (ft): 12. Attachments: Description Summary of Proposal D Detailed Operations Program Œ] BOP Sketch D 14. Estimated Date for Commencing Operation: 5 Permit to Dnll Number: 198-1300/ 6. API Number ../ 50-029-22899-00-00 11542 11858 13. Well Class after proposed work: .... ExploratoryD DevelopmentŒ] 15. Well Status after proposed work: Oil [!] . Gas D <, WAG D GINJD August 2, 2004 16. Verbal Approval: Commission Representative: Date: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Conlact ~~~~~~ame ~~ If /t¿/ ~~~ne ,/:/ . Commission Use Only 1..,/' Conditions of approval: Nolify Commission so that a representative may witness ServiceD Plugged D Abandoned D WINJD WDSPLD Prepared by Sharmaine Copeland 564-4424. John McMullen Sr Production Engineer 564-4711 7/20/04 Sundry Number: . ./ 3 ol/--r3 tÝ' / L/ Plug Integrity D BOP TestD Mechanciallntegrity Test D Location Clearance D Other: r ~.... ')...0 A-A (. zs . ..i I 1-.,[ c), ex ,. ,e '^ t (l I tJ 1 <;; c< . t ('<"6 t-t.Ú't' J Co , ~~.£ ¡It{ La. Lilt. ~d.. l e «t . SUbSeqUe~irb- /ffi BY ORDER DF I / /J Approved &t:/Jf~~ /' THE c_;~: 7 ~ /t,l,ii'l'1 0 RIG I N A L SUBMIT IN DUPLICATE Form 10-403 Revised 06/2004 ò Current Status: Last TD tag: Latest Drift: Min ID: Integrity Issues: Max Deviation: SHHP: 028: PROCEDURE: Badami BI-28 Application for Sundry Approval Proposed Procedure to Secure July 20, 2004 SI gas lifted producer. TIIIO = 2040/2050/0 psi. /' 14019' WLM 0 I /06/00. 3.625" centra1izer to 13870' WLM on 1/12/00. Significant paraffin and asphaltene bui1dup in tUbing since this drift. 3.725" ID thru XN. Confirmed T x IA communication 1/3/2004. Location of leak unknown. 62 deg at 5100'. 10/98 (initial comp1etion)7 5275 psi at 8500' SSTVD. 7/16/2004 7 Est BHP based on fluid level shot = 4600 psi @ 10500' SSTVD 0 ppm during 2003 production. I. RU coil tubing unit. PT BOPE. 2. Liquid pack lA and tubing. 3. Using diesel/xy1ene or other hot fluids. clean-out tubing and liner with 3.65" drift nozzle to 12100' MD. POOH. 4. MU and RIH with a cast iron bridge plug. Set at 12000' MD. Stack weight to confirm holding. / POOH. Freeze protect well. 5. CMIT T x IA to 2500 psi. 6. RDMO. : Top Badami Sand I . " I 12,235' MD; 9060' TVD' .~ BADAMI WELL 81-28 API # 50-029-22899 ,--' ~ ~ z Production Packer 111,542' MD; 8500' TVD 1 ~ - 4 1/2" Liner Top Packer 111,844' MD; 8738' TVD 1 / ;' - Proposed CIBP . '>< ~ 112,000' MD; 8866'TVD I I -7" Shoe h2,034' MD; 8895' TVD I Top of Slotted Liner h 2.075' MD: 8930' TVD I Multi-Lateral Junction Window 112,150' -12,1851 Mol TD HOLE #1 - 14,553' MD; 10,755' TVD TO HOLE #2 - 14,810' MD; 10,683' TVD TO HOLE #3 - 14,310' MD; 10,648' TVD Baker S-3 1115421 Penn anent Packer HES X Nipple OCR 1115481 10 (3.813") HES XN Nipple 9CR ~ 10 (3.725") WLEG 1115791 ELMO CJ ~ fZ 7~ X 4 112- Uner 1118581 I Hanger Packer ~ T 29#ffl. P11 0 .... Fish in , ''' BTC CSG Shoe ~ Uner see Details Top of Slotted Uner 1120751 I Multi-lateral Jooction WindaN 12150 - 12185 RT. REV = 54.8' BF. ELEV = 195' MAX. DEV. = 61 @ 5031' MD 81-28 13-3/8" 68#1ft l-OO. BTC CSG, I 4550 I .~ I 4 1/2P l-80 IBT MOD 12.6#1ft Tubing þ Ib PeI'fOl3tØ1 Summary. 13,752' - 13,172' : 13.800' - 13,810' 13.823' - 13,833' i j 14,015' - 14,035 I ; i 2.75" Predator @ 6 spf 4 1/2- :L-80 IBT I Solid Uner : : FISH: 20' live Pert Gun. OvemU iength ~ 38' wilh 1 - 3/8~ FN See details ,in wel1 file. , . i ~ Mult..Laterat Details , I ~ i Hole'1 , : Tq> c:J SJoled liner , Botbm of Slated üner Hole f.2 , ' Top d Staled lmer BotIDm of Slotted Uner 13973 14551 14146 14800 ~ TREE: 4-1/16-/5000 psi 1 CIW WELLHEAD: 13-5/8"/10000 psi 1 FMC l HES HXO Safety Valve Nipple ID (3.8138) 1 21911 Gas lift Summa-y Cameo 1- KBG-2-LS GLM MD NO ti 3U4 f 2960 5 4037 3710 4 7576 5727 3 10144 7442 2 11167 8180 1 11480 8403 DEV 21 57 48 49 42 40 PBID 14307 Casing Shoe 14308 ,3-30-99 JTP Update JnfOt1T1ation ~ 7-20-04 JCMlTlH Depth Corrections ~ BADAMI WELL 81-28 PERMIT # 98- API # 50-029-22899 BP EXPLORATION, INC. ~ DATE COMMENTS REV. BY BP EXPLORATION Memorandum To' Blair Wondzell fm' Anna Dube Re: 10-404 for perforations on Badami B1-28 January 17, 2000 Blair, Please find attached the 10-404 report for your records for the perforating job on Badami BI- 28 which was completed January 14th, Included are a copy of the wellwork telexes,: a " summary of the wellwork with well test information, a current plot of well test data, and an updated completion'diagram. As you may recall, we requested approval for this work in October. The plan was to initially scrape the tubing of paraffin and run a gas lift design before perforating the well through' the slotted liner. The perforation work was delayed when we were unable to recover the catcher sub after running the gas lift design. We believed the catcher sub to be covered with drilling mud requiring a coil tubing unit clean out. Once we were able to transport the coil unit to Badami, the wellwork continued as planned. you have any questions on the information provided, please feel free to give me a call. Regards, Petroleum Engineer Eastern North Slope 564-5230 STATE OF ALASKA ALASKA 0IL AND GAS CONSERVATION COiv~ClISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown F-IStimulate [] Plugging [] Perforate I~ Pull Tubing []Alter Casing [~ Repair Well I-q Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type ¢;~] well: Development E~ Exploratory [-1Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 55.62' 7. Unit or Property Name Badami Unit 4. Location of well at surface 8. 3858' NSL, 5266' WEL, SEC. 9, T9N, R20E, UM 9. At top of productive interval 3388' NSL, 160 EWL, SEC. 3, T9N, R20E, UM At effective depth 3740' NSL, 23' EWL, SEC. 3, T9N, R20E, UM At total depth 3740' NSL, 23' EWL, SEC. 3, T9N, R20E, UM Well Number B1-28 Permit Number / Approval No. 198-130 399-206 10. APl Number 50- 029-22899-01 11. Field and Pool Badami 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 14310 feet Plugs(measured) 10703 feet 14310 feet Junk(measured) 10703 feet Length Size Structural Conductor 73' 20" Surface 5407' 9-5/8" Intermediate 12001' 7" Production Liner 2464' 4-1/2" ORIGINAL Cemented 260 sx Arcticset (Approx.) 2930 sx PF 'E', 360 sx Class 'G' 185 sx Class 'G' Uncemented Slotted Liner MD 115' 5442' 12034' 11844'-14308' TVD 115' 4523' 8894' 8738'-10701' Perforation depth: measured 11844'- 14310', 13752'- 13772', 13800'- 13810', 13823'- 13833', 14015'- 14035' 4-1/2" Slotted Section: 12075'- 14308', true vertical 8738' - 10103', 10240' - 10256', 10279' - 10287', 10298' - 10306', 10456' - 10472' 4-1/2" Slotted Section: 10246'- 10701' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 at 11580' Packers and SSSV (type and measured depth) Baker S-3 Permanent Packer at 11542'; HES 'HXO' SSSV Landing Nipple at 2191' 13. Stimulation or cement squeeze summary Add Perfs 01/06/00 - 01/14/00 Intervals treated (measured) 13752' - 14035' Treatment description including volumes used and final pressure 14. Prior to well operation: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl 100 Casing Pressure Tubing Pressure Subsequentto operation: 831 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations Signed certifI' t,~,~°reg°l'~ Anna Dube, 564-5230 , '~ Submit In Duplica'~~ 17.1hereby is true and correct to the best of my knowledge Title Sr. Petroleum Engineer, ENS Prepared By Name/Number: Form 10-404 Rev. 06/15/88 Summary of Perforation Wellwork on B1-28 The perforation wellwork on multilateral on B1-28 was completed January 14TM, 2000. The job consisted of running 2 3/4" guns and perforating the 4 1/2"slotted liner in intervals 13,752'-13,772' MD, 13,800'-:[3,810' ND, 13,823'-13,833 ND, and 14,015'-14,035' MD. We were unable to perforate the bottom 20' of the bottom interval due to tagging fill. Problems due to tagging fill are believed to be caused by drilling mud entering the leg from the junction at 12,136' HD. Although we were able to perforate the final interval, a perforation gun has been left in the hole covered by fill. Prior to the job, B1-28 was tested at 111 bopd with a GOR of 1800 and a gas lift rate of :1.8 mmscfd. The well work resulted in a significant increase in productivity. The well was brought on line and tested at 831 bopd with a GOR of 722 and a gas lift rate of 2.1 mmscfd. Below is a summary of the day to day operations. B1-28 FCO and Reperf 12/9 Thu Hold HAZID 12/13 IVlon Nordlander visits Badami 12/14 Tue DS starts shipping coil from Kenai to Deadhorse 12/15 Wed Coil arrives at DeadhOrse. Start prepping well 12/16 Thu Start moving equipment to Badami by Rolagon. 12/17 Fri More hauling. Nordlander to Badami. l~ICll0r~t~]~l 12/18 Sat More hauling. Prepping equipment at Badami. 12/19 Sun Spotted coil. Prep work ongoing. 12/20 Non Rigged up coil, started 24 hour operations at 18:30. 12/21 Tue Cleaned out hydrates, cleaned out to top of fish. Prepared for fishing. 12/22 Wed Fished catcher sub from tailpipe. Start cleanout, injector head broke. 12/23 Thu Flew out mechanics. Found needed gears as well as motors. 12/24 Fri Mechanics removed broken parts. Waiting on spares. 12/25 Sat Waiting on spares. 12/26 Sun Waiting on spares. 12/27 Mon Nordlander off, Kirby on site. Parts arrive, start repairs. 12/28 Tue Completed repairs, clean out to 14,158 ft. Rig down coil. Crane broke. 12/29 Wed Atlas could not get below ,~4000 ft. Blizzard conditions. 12/30 Thu Blizzard continues. No flights - no spares for crane or bailer for wireline. 12/31 Fri Phase II:[ conditions. 1/1 Sat Blizzard conditions. 1/2 Sun Weather improving. Flying again. Ran bailer. Still no go below N4000ft. 1/3 Non Waiting on crane parts 1/4 Tue Crane repaired, prepare to rig up coil. 1/5 Wed Rigged up coil, prepared Biozan, started FCO. 1/6 Thu Cleaned out well. Rigged up to perforate ......... 1/7 Fri Perforated 14,015'-14,035' MD. Atlas E-line engineer sent to Endicott with a non- work related medical problem. 1/8 Sat Atlas engineer returned to Badami. While running in the hole, the line stranded. The disarmed perf gun got wedged in the lubricator with a 20' bird nest of wire. Worked to get things running properly to continue perforations 1/9. Pumped 20 bbls diesel down hole to freeze protect. 1/9 Sun 1st run: GR broke during tie-in. Abort run to fix tool. 2nd run: Line shorted at 2000'. Abort run to re-head. 3rd run: Tagged fill at about 13,991' (can not perforate 13,995' -14,015' interval). PUH and shoot 13,752' - 13,772 with 700 psig underbalance. 4th run: Line shorted at 12,000'. Abort run to re-head. 5th run: Line shorted at about 12,200'. Abort run to re-head. Discover that the wire twisted and broke in the cable head. Left ~ 30' fish in hole. Pumped 10 bbls of methanol. 1/10 Mon Had fishing tools flown out to Badami. Unable to get past liner hanger packer with fishing tools. Well is freeze protected. 1/11 Tue Able to get into the liner with fishing tools but tools came back packed with mud. Bailer came back full of mud. Have mud up to 13,860' MD. Fish stuck at about 13~950' MD. 1/12 Wed RIH with bell guide, centralizer, and pulling tool. Sat down at 13,870'. Unable to latch gun. 1/13 Thu Ran in hole with bailer. Sat down at 13,842". Appears upper lateral is flowing mud into the slotted liner. Send engineer out for medical attention. 1/14 Fri Convert to E-line. Shot 13,823'-13,833' and 13,800' -13,810'. POP well with gaslift and methanol. RECEIVED ~chorag~ Well Test Plot WELL: B1-28/BADAMI Dates from 08/28/1998 to 01/17/2000 A $ O N D J F __M __A__ M__J __ J A S__O__N D J ..,__v , - 1991~ '----- , , , 1999 , , ' , ' 2000- ~;~¢ , _ .... . ....... ' , .. , , ' , , , , JAN oo0 , , . , , lOOO ,- : ' :j~ : , ,, : ,, , ~ r ; : , , ~oo9°° ' ..... ,, . :, ~ : % ': : ~,~,~'nit&'GaSC0ns. Co~'.~.:':-~--; -:-.-::-.... :--. : _ 700 , ~o 500 - - " ' ' , ~ ' ~' I- ' -, ...... ~ ..... , ................ ' ..... , .... ' , ' , ~ ~.;,, , ,.. ~ ........ . ............ : ........... ~ ~ .... ~~.._~-~ ........................... /', ............ , , , ~ ,~ , , , , , ,~ r ~, f~ ,, ~ ,-~ , , / . , ' ~o ........... ' ..............~ ~b ~ ..... ~ X~ ............................ ~ ', ................ ~ _~ ........ ~_ ~~~~ .~. ~-' ....... ~ ..............~-~ .............. ~ ~ ~ e~, ................ .~-. ,,, .......... ,' ................. ~o., ....... : ..........:..~. ~.~ ~ -,~.. ..................... , ............ ,, .............. ~ ,~~---,-,~1-.-~ .... ~ :.-~ ....................................... 60 I1_ ......... ~o _: ~ : ..... : .... ~ ~, ..... :':.".~' . '~. ~o : ............ : ~: ,, : ....: ............. : ....... : ,, ....... :~-~.?.,-.,--~ ....... : .............. : .................................. ~ ~ ' ,; ' , : ' , ' , T ' ~ ~ ~ . A S O N D J F M A M J J A S O N D 1998 1999 0 5000 4000 3000 2000 200 120 100 80 60 40 20 0 , i O F M A N D J 1998 1999 2000 10:35:10 January 17 2000 CPE V1,2.03 Gross Fluid O I Rate ~,~ - G.O.R. · Gas Lift Man. Pressure Man. Temp. Kelly bushing to wellhead/GL (fi) 35.3 Wellhead to sea level (fi) 19.8 F5 A5 OD ID: weight: MD ;i : TVD Der :inch inch Lbs/ft :: :rkb .: Ss ;:deg Conductor 20.000 19.124 91.5 115.3 60.2 0.0 L-80 IBT Production Tubing 4.500 3.958 12.6 HES 'HXO" Safety Valve Landing Nipple 4.500 3.813 2191.0 2132.0 0.0 Surface Casing 9.625 8.681 40 5444.0 4475.0 54.0 Camco KGB2LS 4 1/2" x 1" GLM 3047.0 2960.0 25.9 Camco KGB2LS 4 1/2" x 1" GLM 4037.0 3648.0 54.0 Camco KGB2LS 4 1/2" x 1" GLM 7577.0 5791.0 49.8 Camco KGB2LS 4 1/2" x 1" GLM 10144.0 7539.0 44.6 Camco KGB2LS 4 1/2" x 1" GLM 11168.0 8282.3 42.5 Camco KGB2LS 4 1/2' x 1" GLM 11480.0 8513.9 41.8 Baker S-3 Permanent Packer 5.875 3.958 23-29 11542.0 8560.5 41.3 HES "X" Landing Nipple 4.500 3.813 11548.0 8565.1 41.3 -lES "XN' Landing Nipple 4.500 3.725 11568.0 8580.2 41.2 Wireline Entry Guide 5.250 3.958 11580.0 8589.2 41.1 7' x 4 1/2" Liner Hanger / Packer 11843.7 8793.2 38.6 7' Intermediate Casing 7.000 6.1'84 29 12035.0 8944.0 38.3 Bottom 4.5' Solid Liner/Top 4.5' Slotted 4.500 3.958 12.6 12075.0 8974.4 39.6 Kick Off Point 12136.0 9018.4 42.4 ]8. 000 ~~~t!1_ ~tsstor, Mid-pay (for GL design) 13800.0 10199.7 35.5 2-3/4' 6 spf 60o phasing 13752-13772 2-3/4" 6 spf 600 phasing 13800-13810 2-3/4" 6 spf 600 phasing 13823-13833 Fish: perf gun 13950 Top 4-1/2' Slotted Liner - Hole #1 13977.0 10127.7 45.7 2-3/4' 6 spf 600 phasing 14015-14035 Top 4-1/2' Slotted Liner - Hole #2 14150.0 10812.2 21.5 Fish: 14.5' jet cutter & fidng head 14308.0 10631.2 29.2 4-1/2' Slotted Liner- Hole #3 4.5O0 3.958 12.6 14310.0 10633.0 29.2 BI-28 BI-28LI Date Rev by Comments 6/1711998 B.Tumbull Initial design 111511998 M. Sauve Corrected to actual drilling depths and tubing tally ~/17/20e0 A. Dube Add perf and fish. A. Dube :: : :Prod:acer:i:; m01tilateral :::: :/::::: To: Anchorage Production Engineering Location: Badami From: Nordlander Date: 12/21/99 Operation: Badami B1-28 Hydrate Cleanout Cost Code: 880466 Previous: $181,022 Today's: $47,503 Est. Costs: $228,525 Summary Jetted hard hydrates from surface to 4280' ctmd with heated recirculated diesel w/drag reducer. Returns to surface slightly contained gas with mostly diesel and 1-2% water with sparse 1-2% solids which is sand and other which floats on top of water yet heavier than diesel. It also appears that the annulus was either hydrated off or frozen. Continued jetting downward to cleanup tubing; jetted down to 11546 ctmd cleaning up top of fish. Did not see mud top with coil. Jetted up at 80%. Prepared coil for fishing ops. Operation 12/21/99 Tuesday Pressure tested. BOP tested, & B1-16 flowline test. Heated coil and hardline with hot diesel; From flowback tank, circulated diesel down coil, through separator, and back to flowback tank. Baker fishing supervisor & tools make flight. Atlas operators make flight for perf job/gauge run. Cleaned out hydrate, and cleaned out on top of catcher sub. Changed out packoffs. 12/22/99 Wednesday Tentative Plan Continue with operations: Fish catcher sub; cleanout liner. E-line gauge/junk basket. Perforate well. .. - Start demobilization. . 12/23/99 Thursday . Tentative Plan Continue demobilization. 12/24/99 Friday Tentative Plan Finish demobilization. 12/21/99 Time Operation Ru DS #15D9436, 14,355' of tapered 1-3/4" (ctv 31.5 bbls). 5:20 Work on hardline, work on separator predicament. 8:32 Start BOP test. 9:49 Good test, fill up separator. 10:19 Test B1-16 for open flowline. Test separator to 1000 psi. 10:49 Good, break off to recover ball. Mu 3" jet swirl nozzle and checks. 11:24 Hold hydrate cleanout safety meeting. 11:38 Pressure test lubricator. 11:47 Start heating and circulating hot diesel. 37" on tank. 12:55 Pipe is nice and hot, open well. Initial Well Status Whp lap 0ap GIp FIp Fit psi psi psi psi psi °F Sh utin 240 1800 0 2160 n/a n/a Operation: Badami B1-28 Hydrate Cleanout Page: 2 Time Depth Rate Ctp Whp Stage Rate Tank Remarks ft bpm psi psi bbls rtns strap 13:02 surf 30 37 Rih 13:04 5 Tag, start pumping hot diesel. 13:09 7 1.7 2300 1400 8 13:38 57 2.4 1500. 62 1.5 36 Open choke. 13:48 48 2.4 2830 1380 75 2.2 Some intermittent gas. 14:15 70 2.6 2720 1380 130 Open, choke. 14:25 3200 1000 154 36 Open choke. 14:30 73 2.6 3100 167 2.0 Open choke. 15:27 121 2.6 3310 580 305 2.0 16:23 329 2.6 3360 500 420 3.3? 36 16:58 924 2.6 3320 380 506 1.8 35 17:31 1475 2.6 3110 200 580 1.9 36 Electronic counter is off; start using the mechanical. 1356 18:05 1519 2.6 3080 150 658 2.1 36.5 19:03 1580 2.6 3360 550 786 1.9 20:00 1800 2.6 3540 600 1020 1.9 36.7 20:56 2004 2.6 3580 640 1050 1.8 21:29 2735 1125 Shut down, leak on swivel. Contain and curtail leak. Badami Environmental contacted; 22:42 0 Pressure test, good, circulate, good, start heating diesel. 22:53 2700 2.0 1400 0 1137 38 Start choking well, rih jetting. · 23:56 3846 2.4 3620 580 1249 1.0 37 .. - . 12/22J99 0:28 4280 2.0 3580 600 1314 Looks like it finally broke through. IA 800 psi. 0:59 6240 2.0 3680 620 1377 1.6 40 "-' -~ 2:35 11546 2.0 3660 340 1.5 Tag; cleanout wellbore and fish area. 2:45 1572 Jet out of hole. 4:01 3715 2.0 3680 220 1715 1.5 43 IA 500 psi. 4:25 1500 2.0 3720 360 1755 Switch to meoh spear followed by fresh diesel. 4:52 surf 150 1792 51.5 Bleed down, break off, change packoffs. Final Well Status Whp lap 0ap GIp FIp Fit psi psi psi psi psi °F S h utin 150 500 0 2100 n/a n/a Fluid Summary 250 Diesel with drag reducer, recirculated 1755 bbls. 50 Diesel. JAN 300 Total ............. Jet Swirl Nozzle Bottom Hole Assembly # 1 ~'~"'~"~" Tool String Descriptions O.D. I.D. Len,gth Comments DS ct connector. 2.00 0 DS dual check valves. 2.00 1.00 0.94 Jet swirl nozzle 3.00 0.50 7 down, 4 around swirl. Total Length 1.44 Operation: Badami B1-28 Hydrate Cleanout Page: 3 RECEIVED JAN 18 ~OJ)O Alaska Oil & GasColt&~ Anchorage To: Anchorage Production Engineering Location: Badami From: Nordlander Operation: Badami B1-28 Fish & Cleanout, Cost Code: 880466 Date: 12/22/99 Previous: $241,172 Today's: $55,898 Est. Costs: $297,070 Summary Ran in hole and fished catcher sub from "XN" at 11529 ctmd; pooh. No gas lift valve was found in catcher sub. Catcher sub was filled with solids (probably drilling mud). Made up 3' jetting nozzle and rih jetting recirculated diesel. Did not tag up on any suspected solids; jetted down to 12500 and was making a jet pass up tailpipe. At 12600 coil started to runaway. Caught it and parked, trouble shoot. Set slips and wait for hydraulic motors and mechanic to fly out to location. , , Operation 12/22/99 Wednesday Fish catcher sub; no gas liftvalve found. Started liner cleanout. 12/23/99 Thursday Tentative Plan Fly out mechanic and motors. .Change out motors. Continue with operations: cleanout liner. 12/24/99 Friday Tentative Plan E-line gauge/junk basket. Perforate well. Start demobilization. 12/25/99 Saturday Tentative Plan Continue demobilization. 12/26/99 Sunday Tentative Plan Finish demobilization. 12/21/99 Time Operation Ru DS #15D9436, 14,355' of tapered 1-3/4' (ctv 31.5 bbls). 4:52 Bleed down, break off, change packoffs. 7:14 Pu lubricator. 7:47 Stad making up fishing tools; connector etc. j~',~ 8:32 Pull test, pressure test. . ..... 8:47 Mu jars and GS. r~l~a,0il&GasConS,~m~~ 9:51 Pressure test hardline and lubricator to 4000 psi. '~'--: Artr.,ftora~ 10:04 Rih w/fishing tools, bha#1. Initial Well Status Whp lap 0ap GIp FIp Fit psi psi psi psi psi °F Sh utin 650 1000 0 2100 n/a n/a Time Depth Rate Ctp Whp Stage Rate Tank Remarks ft bpm psi psi bbls rtns strap 10:11 365 250 Leak in lubricator, park, close pipes. Wait on man lift. 12:30 Pooh. Replace o-ring. I Operation: Badami B1-28 Fish & Cleanout. Page: 2 12:50 surf 160 Pressure test 4000, good', rih. 15:19 11529 230 Tag fish. 15:21 11529 Latch and pooh. 17:50 surf 220 At surface, bleed down. 19:00 Break off tools, catcher sub retrieved, no gas lift valve. Dried up solids (maybe drilling mud)in catcher sub. Mu bha #2, 3" jetting nozzle 19:47 Stab on well, Icad coil with diesel. 20:33 Pressure test 4000, good open ia valve (600 psi). 20:41 2.3 3480 210 Rih jetting 130°F recirculated diesel. 20:54 500 3770 240 30 1.9 63.5 Open gas lift to 0.5 mm. 22:00 7100 1.9 3700 260 162 68 Open liquids to B1-16. 22:59 11283 1.8 3540 260 274 1.7 39.5 Take liquids to tank. 23:09 11910 1.8 3530 270 292 Jetup. IA1600. BU is 142 bbl or 434 pumped. 23:17 11540 3550 260 Jet down. 23:35 12500 3680 270 338 Jet up, increase gas lift to 1.0 mm. 23:55 10600 Run away '- 23:57 12312 Caught it. Park and circulate; trouble shoot. 12/23/99 0:57 1.8 3530 240 485 53 IA 1400 1:31 1.5 536 52 Red rate. Having losses. Shut slips for trouble shoot. 1:57 271~0 220 575 49.5 Still losing returns. 3% Solids & 17% Water?? Oil is 0.9032 or 25°APl. 2:58 1.4 2450 250 - 660 1.7 51.5 Not losing returns, well is flowing again. 6:00 210 914 61 Still circulating Current Well Status Whp lap 0ap ' GIp FIp Fit psi psi psi psi psi °F Flowing 210 1400 0 1400 210 72 Baker Hydraulic Fishing String Bottom Hole Assembly # 1 Tool String Descriptions O.D. I.D. Length Comments Baker fishing neck 3-1/8 1 0.95 Baker check valves 3-1/8 1 1.53 Baker up & down Bowan jars 3-1/8 1 6.80 Baker hydraulic disconnect 3-3/8 13/16 1.58 7/8" ball setting. Baker 4" hydraulic "GS" spear 3-1/2 1/2 1.70 Total Length 12.56 Jet Swirl Nozzle Bottom Hole Assembly # 2 Tool String Descriptions O.D, I.D. Length Comments DS ct connector. 2.00 0 DS dual check val~/es. 2.00 1.00 0.94 Jet swirl nozzle 3.00 0.50 7 down, 4 around swirl. Total Length 1.44 RECEIVED JAN 1 8 2000 Alaska 0il & t3~ Co~ ~ Anchoraoa To: Anchorage Production Engineering Location: Badami From: Nordlander Operation: Badami B1-28 Coil Repair Cost Code: 880466 Date: 12/23/99 Previous: $284,710 Today's: $47,973 Est. Costs: $332,683 Summary Continued circulating heated diesel & produced fluid down coil and through the separator. Well was making about 200-500 bopd above what was circulated. Trace amounts of solids and water in spin outs. At times, diverted production to plant to keep tank levels down. Continued to tarp injector, well, and scaffolding. Flew out mechanic, tools, and motors. Weather very inclement. Had to wait for winds to die down to operate man basket. Mechanics still working on injector head at time of report. It looks as though this is not just a motor problem but has gear problems as well. Sending for additional spare parts from Rock Springs and maybe Kenai. Operation 12/23/99 Thursday Flew out mechanic and motors. Worked on motors and injector head. 12/24/99 Friday Tentative Plan Work on injector; delineate problem. Prepare injector for spare pads. Continue to circulate well. 12/25/99 Saturday Tentative Plan Work on injec!or; delineate problem. Prepare injector for spare parts. Continue to circulate well. 12/26/99 Sunday Tentative Plan ~ ' :.~.~ .~., Repair Injector. - Continue to circulate well. - ;.- 12/27/99 Monday Tentative Plan Repair Injector. Continue to circulate well. 12/28/99 Tuesday Tentative Plan Pooh and check tubing and injector. Continue with liner cleanout. 12/29/99 Wednesday Tentative Plan E-line gauge/junk basket. Perforate well. RECEIVED Start demobilization. 12/30/99 Thursday Tentative Plan Continue demobilizatiOn. 12/31/99 Friday Tentative Plan Finish demobilization. ~8~l~a,~l~ ~'-,u,'~, ,,,, ........... 12/23/99 IJ Time J Operation Ru DS #15D9436, 14,355' of tapered 1-3/4" (crv 31.5 bbls). Time Depth Rate Ctp Whp Stage Rate Tank Remarks ft bpm psi psi bbls rtns strap 6:00 12312 1.5 2000 210 914 61 Still circulating. 12/24/99 Operation: Badami B1-28 Coil Repair. 2.00 Iozzle 2.00 0 ~ 3.00 0.50 1.44 JA,'q 10, RO00 ~{aska Oil & GasCons.~ ~cherage To: Anchorage Production Engineering Location: Badami From: Nordlander Date: 12/24/99 Operation: Badami B1-28 Coil Repair Cost Code: 880466 Previous: $332,683 Today's: $47,973 Est. Costs: $380,656 Summary Continued circulating heated diesel & produced fluid down coil and through the separator. Well was making about 100-200 bopd above what was circulated. Trace amounts of solids and water in spin outs. At times, diverted production to plant to keep tank levels down. Weather is good. Mechanic was able to pull out all gear box and motors. Waiting for spare parts to arrive. Operation 12/24/99 Friday Continued to circulate well. Worked on motors and injector head. Prepared injector for spare parts. 12/25/99 Saturday Tentative Plan .. Wait on spare pads. Continue to circulate well. 12/26/99 Sunday Tentative Plan Repair Injector. Continue to circulate well. "12/27/99Monday Tentative Plan Repair Injector. , .. . , Continue to circulate well. - - -. .. , . 12/28/99 Tuesday Tentative Plan '" .. ~ ._-. Pooh and check tubing and injector. Continue with liner cleanout. 12/29/99 Wednesday Tentative Plan E-line gauge/junk basket. Perforate well. Stad demobilization. ~ ~ ~ 12/30/99 Thursday Tentative Plan Continue demobilization. ..~. ,,, ,, ,.~ ~ . _ 12/31/9'9Friday Tentative Plan dAN 1 Finish demobilization. .......... ~__ ~___ 12/24/99 "t' Time ] Rul DS#15D9436, 14,355' of tapered 1-3/4" (ctv 31.5 bbls). Anchorage Operation Time Depth Rate Ctp Whp Stage Rate Tank Remarks ft bpm psi psi bbls rtns strap 6:00 12312 1.5 1800 210 3074 1.5 60 Still circulating. 17.J25/99 1.6:00{ 1231211.5122001210152341 1.5 I 60 I Keeping tank strap S0-70'. Operation: Badami B1-28 Coil Repair. Page: 2 Current Well Status Whp lap 0ap Gip FIp Fit psi psi psi psi psi °F Flowing 210 1400 0 1400 210 72 Jet Swirl Nozzle Bottom Hole Assembly # 2 Tool String Descriptions O,D. I.D. Length Comments DS ct connector. 2.00 0 DS dual check valves. 2.00 1.00 0.94 Jet swirl nozzle 3.00 0.50 7 down, 4 around swirl. Total Length 1.44 RECEIVED JAN ] 8 20~0 To: Anchorage Production Engineering Location: Badami From: Nordlander Operation: Badami B1-28 Coil Repair Cost Code: 880466 Date: 12/25/99 Previous: $343,199 Today's: $18,928 Est. Costs: $362,127 Summary Continued circulating heated diesel & produced fluid down coil and through the separator. Well was making about 100-200 bopd above what was circulated. Trace amounts of solids and water in spin outs. At times, diverted production to plant to keep tank levels down. Weather is good. Waiting for spare parts to arrive; worked on motor. Operation 12/25/99 Saturday Wait on spare parts. Continued to circulate well. 12/26/99 Sunday Tentative Plan Repair Injector. Continue to circulate well. 12/27/99 Monday Tentative Plan Repair Injecto!. Continue to circulate well. 12/28/99 Tuesday Tentative Plan Pooh and check tubing and injector. Continue with liner cleanout. 12/29/99 Wednesday Tentative Pian E-line gauge/junk basket. Perforate well. Start demobilization. 12/30/99 Thursday Tentative Plan Continue demobilization. ~v~ 12/31/99 Friday Tentative Plan Finish demobilization. ~~& Gas Cons. ~rnm~f~r~ Anchorage 12/25/99 Time Operation Ru DS #15D9436, 14,355' of tapered 1-3/4" (ctv 31.5 bbls). Time Depth Rate Ctp Whp Stage Rate Tank Remarks- ft bpm psi psi bbls rtns strap 6:00 12312 1.5 2200 210 5234 1.5 60 Still circulating. 12/26/99 I 6:00 I 12312 I 1.4 I 2280 I 210 I 7250 I 1.5 I 60 I Keepingtankstrap50-70". 'Current Well Status Whp lap 0ap GIp FIp Fit psi psi psi psi psi °F Flowing 210 1400 0 1400 210 72 Operation: Badami B1-28 Coil Repair. Page: 2 Jet Swirl Nozzle Bottom Hole Assembly # 2 Tool Strin~l Descriptions O.D, I.D, Length Comments DS ct connector. 2.00 0 DS dual check valves. 2.00 1.00 0.94 Jet swirl nozzle 3.00 0.50 7 down, 4 around swirl. Total Len~lth 1.44 To: Anchorage Production Engineering Location: Badami From: Nordlander Date: 12J26/99 Operation: Badami B1-28 Coil Repair Cost Code: 880466 Previous: $344,774 Today's: $19,828 Est. Costs: $364,602 Summary Continued circulating heated diesel & produced fluid down coil and through the separator. Circulating fluids appear to be mostly reservoir oil with little diesel left. Signs of paraffin are evident. Well was making about 50-100 bopd above what was circulated. Trace amounts of solids and water in spin outs. At times, diverted production to plant to keep tank levels down. Weather is good. Continued to work on motor; waiting for spare parts to arrive today. Operation 12/26/99 Sunday Wait on spare parts, work on motor. Continued to circulate well. 12/27/99 Monday Tentative Plan Repair Injector. Change out circulating fluids to diesel. Continue to circulate well. 12/28/99 Tuesda,,y Tentative Plan Check tubing and injector. Continue with liner cleanout. 12/29/99 Wednesday Tentative Plan E-line gauge/j.unk basket. Pedorate well. Start demobilization. 12/30/99 Thursday Tentative Plan Continue demobilization. 12/31/99 Friday Tentative Plan Finish demobilization. 12/26/99 Anchorage tTime ] Operation Ru DS #15D9436, 14,355' of tapered 1-3/4" (ctv 31.5 bbls). Time Depth Rate Ctp Whp Stage Rate Tank Remarks ft bpm psi psi bbls rtns strap 6:00 12312 1.4 2280 210 7250 1.4 60 Still circulating. 12/27/99 6:00 1 12312 I 1.4 I 2900 I 210 I 9266 I 1.4 I 60 I Keepingtankstrap 50-70". Reduce to 30-60. Current Well Status Whp lap 0ap GIp FIp Fit psi psi psi psi psi °F Flowing 210 1600 0 1600 210 68 Operation: Badami B1-28 Coil Repair. Page: 2 Jet Swirl Nozzle Bottom Hole Assembly # 2 Tool Strin~l Descriptions O.D. I.D. Length Comments DS ct connector. 2.00 0 DS dual check valves. 2.00 1.00 0.94 Jet swirl nozzle 3.00 0.50 7 down, 4 around swirl. Total Length 1.44 ,,fAN 18 8000 ~ & Gas Cons. Commissl0r~ Anchorage To: Anchorage Production Engineering Location: Badami From: Operation: Kirby Walker Badami 91-28 Coil Repair/Clean Out Cost Code: 880466 Date: 12/27-28/99 Previous: $364,602 Today's: 12/27 - $48,500 12/28 - $54,700 Est. Costs: $467,802 Summary Continued circulating new batch of heated diesel down coil and through the separator. Welltest read -2,100 bopd - equal to circulating rate of 1.5 bpm. Trace amounts of solids and no water in spin outs. Parts arrived from Deadhorse and repair operation commenced. Repair and test injector head. Pull tension and open slips. PUH and visually inspect injector. Looks good- RIH to 12,600' jetting. PUH to TT. RIH. Take 100' bite and PUH 200'. Continue as such to 13,000' and PU to GLM #1. See no sign of fill but PTS reports traces of solids (0.1% - 0.25%) and slugging both gas and oil- no water. RIH continuing to take 100' bites to 13,500'. Notice that depth counter is reading -100' shallow. Calculate length of coil left on reel and adjust depth. Continue to RIH cautiously. Lose weight at -13,700' - lifting fill to -13,720. Start 100 bbl Biozan sweep with coil parked at 14,158'- reciprocate periodically. (This is as deep as possible with length of coil.) Displace Biozan with 295 bbl of diesel. POOH from 14,158' with 10 bbl of diesel out of nozzle. Obtain higher concentration of solids (3.0%-5.0%) on Biozan sweep. Begin pumping nitrogen to purge coil at 2,500'. On surface with coil- SI swab and continue displacing diesel through PTS. S/D nitrogen pump and RB coil unit to allow Baker Atlas t.o RU i for drift. Operation 12/27/99 Monday Wait on spare parts. Repair injector. 12/28/99 Tuesday _, . Repair Injector. __ Continue to circulate well. Continue with liner cleanout to 14,158'. Rig back CTU- RU Atlas for drift run. 12/29'99 Wednesday Tentative Plan Perforate well. Start demobilization. 12/30/99 Thursday Tentative Plan Continue demobilization. 12/31/99 Friday Tentative plan Finish demobilization. 12/27/99 Time Operation 19:45 Parts arrived from Deadhorse- begin repairs. 12/28 02:45 Ready to open slips. Hold safety meeting with entire crew. 03:10 Equalize riser- open slips. RIH. 13:08 POOH jetting. 15:30 On surface- RDFN. Operation: Badami B1-28 Coil Repair. Page: 2 Time Depth Rate Ctp Whp Stage Rate Remarks ft bpm psi psi bbls rtns 03:00 12312 1.5 1590 210 5234 1.5 Still circulating. 03:10 12312 1.5 1570 220 1.5 Openslips- PUH. 03:20 12000 2.4 1663 230 21 2.4 Park coil. Visually inspect injector. 03:30 12000 2.4 2060 225 28 2.0 RIH jettin9. 03:41 12600 2.7 1950 220 50 2.1 Park coil and circulate. 03:45 12600 1.9 2474 220 58 1.5 PUH. 04:00 11750 2.0 2600 225 90 1.7 Open full choke. 04:10 11700 1.8 3460 230 115 1.7 Increase charge pressure- full returns. Recip. coil 04:35 11700 1.8 3646 215 160 1.7 RIH. Open inlet more- getting full returns. 04:50 12700 1.8 3709 238 180 3.0 Parkcoil. Recip. 04:55 12700 1.8 3617 240 190 1.8 RIH. 05:01 12810 1.8 3610 237 200 1.8 Parkcoil. Recip. 0.15solids 05:35 12810 1.8 3'880 211 262 2.0 RIH. 05:43 12900 1.8 3890 204 275 2.0 Parkcoil. Recip. 0.25solids 06:06 13000 1.8 3520 300 319. PUll jetting. 06:51 11465 1.8 3408 249 390 1.75 Park coil. 07:15 11465 1.8 3580 226 434 1.7 RIH. 07:54 13100 1.8 3828 184 495 Park - recip. ~,~rm~ ~,.,,.,.,.,... 08:01 13100 1.8 3973 174 507 1.9 PUH 08:26 12760 1.8 3690 158 547 Slug to surface. No solids- 8500 b~)~l-."~['~." 08:35 13200' 1.8 3033 279 558 2.1 PUH. 08:46 13100 1.8 3054 258 580 2.3 Parkcoil. Gasrate off scale. 09:00 13100.. 1..8 2995 251 605 1.8 RIH. Gas rate-2 mmscf i, 09:06 13400- 1.8 2964 245 611 1.8 PUH. 09:10 13300 1.8 3008 214 617 1.9 Rill. 09:20 13500 1.8 3005 212 632 1.7 PUH. Rate 2400 bopd, 4.5 MMSCF 09:28 13400 1.8 3028 228 646 1.8 Increase lift gas to 2.0 mmscf. Park coil 2,500 bopd, 1.3 mmscf 09:36 13400 0 0 235 655 S/D pump. Hook up biozan and diesel. 09:46 13350 1.8 1820 336 662 Resume pumping. 10:11 134607 0 0 306 697 S/D pump. Depth incorrect. 10:23 13464 1.8 2100 290 697 Resume pumping. 10:38 13471? 0 13 280 S/D pump. 1.6 mmscf- 2400 bopd 11:03 134717 1.0 20 230 706 Resume pumping. POOH. 900 bopd 11:30 135027 1.4 1120 247 736 Lose weight- signs of fill. Start biozan. PU - 37,700# 11:52 133597 1.4 417 276 33 Biozan at nozzle 12:04 14158 1.8 517 256 54 Park coil. Adjust depth. 12:24 14158 1.8 550 256 88 3.0% solids 12:33 14158 0 0 242 100 Finish biozan. Set up to stad diesel. 12:38 14158 1.8 1020 292 100b Stad diesel behind. 13:00 14158 1.7 1993 249 32 Biozan out of nozzle. 3000 bopd, 2.5% solids, 2 mmscf 13:08 14158 1.7 1878 1.6 42 2.2 POOH jetting. 13:12 14055 1.6 1878 256 50 Hydraulic leak on injector. 13:19 14055 1.6 1899 202 58 POOH- watching for leak. 13:46 12216 1.6 1734 237 96 5.0%solids, 0.5% biozan 14:10 9900 1.5 1209 265 130 Increase GL rate to 3.0 mmscf 15:04 3080 0 0 380 205d S/D pump- getting gasto separator. Operation: Badami B1-28 Coil Repair. 15:101 2500 1500scfl 1000 I 237 15:29 I 0 I 0 } 1250 I 172 Page: 3 I I Istart nitr°gen' 200gal On surface with coil. RBFN. (18,624 scf) Current Well Status Whp lap 0ap GIp FIp Fit psi psi psi psi psi °F FL_ 220 1200 0 1620 210 72 Fluid Summary 100 Freshwater w/1.65 #/bbl Id-visc polymer 941 Diesel w/ friction reducer* 1041 Total (bbls) 200 gal Nitrogen (18,624scf) * a total of -500 bbl were used for circulating Jet Swirl Nozzle Bottom Hole Assembly # 2 Tool Strin9 Descriptions O.D. I.D. Length Comments DS ct connector. 2.00 0 DS ~lual check valves. 2.00 1.00 0.94 . '._ - Jet swirl nozzle 3.00 0.50 7 down,, 4 around swirl. Total Length 1.44 R¢ CEiVED JAN 18 2000 _jas J & Cons. Commiss! n Anchorage To: Anchorage Production Engineering Location: Badami From: Bundy Date: Operation: Badami B1-28 Previous: Today's: Cost Code: 880466 Est, Costs: 1/04/00 $651,810 $34,778 $686,588 Summary Hydraulic pump on the crane was replaced. Began hauling water to mix 2% KCI and Biozan. Load and heat water. Prep to start clean out tomorrow. Operations 1/4/00 Tuesday Finished clean up of location. Thawed water supply hole. Repaired crane. Mixed KCL water. Loaded trucks and tanks with fluids. Mixed Biozan. 1/5/00 Wednesday Tentative Pian Rill with coil and complete fill clean out. Freeze protect well. Rig back CTU- RU Atlas for drift run. 1/6/00 Thursday Tentative Plan Perforate well. Start demobilization. 1/7/00 Friday Tentative Plan Continue demobilization. 1/8/00 Saturday Tentative Plan Finish demobilization. Current Well Status Whp lap 0ap GIp FIp Fit psi psi psi psi psi °F SI 1400 1400 0 1400 na na 'JAN 18 2000 ~_a~ra ~ & Gas Cons. Comm~g~ Anchorage To: Anchorage Production Engineering From: Bundy Operation' Badami B1-28 Cleanout Cost Code: 880466 Location: Badami Date: 1/05 -1/06/00 Previous: $651,81 0 1/5- 1/6100 $96,080 (Perf not included) Est. Costs: $747,890 Summary Finished loading 2% KCI water. Changed out injector pack-off. Pressure tested lines to 4000 psig. Pumped hot diesel to flush all surface lines and PTS equipment. RIH with 14,351' of tapered 1-3/4" ct. pumping at minimum rate. Bled down WHP to facility. Encountered restriction at 3960'. Pumped 150 deg F- 2% KCI and jetted through restriction (3960' - 4000'). Reciprocated 3800' to 4100' jetting Biozan. Swept hole clean with 2% KCI from 4100' then continued RIH. Encountered slight restriction around GLM #1 (11,400' - 11,500'). Reciprocated across GLM #1. Continue RIH jetting w/KCl. Found slight restriction from 12,200' to 12,225'. Worked through and switched to Biozan. Continue RIH to maximum length of coil (reel empty) estimated 14,280' based on DS coil records (13,960' counter depth). Pumped additional 20 bbls of Biozan out nozzle while at maximum depth. Switched to KCI. Blew packing on DS triplex. Swapped over to HB&R back-up pump. Start POH at 80%. Encountered no over pull while POH. At 3700' began laying-in diesel for freeze protection. Purged coil and surface lines with N2. No significant solids were recovered from the initial sweep across the interval 3800' to 4100', it's felt this restriction may have beer~ paraffin. Diesel / KCI returns with trace solids were noted while RIH. The Biozan sweep off bottom produced 0.5% very fine solids strung out through the gel returns, possibly drilling mud. The increase in gel and solids at the end of the job may have been picked up while coming back up through the 7"production csg. between the liner lap and the tubing tail. Operation 1/5/00 Wednesday Finish loading water. RIH with coil and complete fill.clean out. Freeze protect well. 1/6/00 Thursday Tentative Plan Rig back CTU- RU Atlas for drift run. Perforate well. 1/7/00 Friday Tentative Plan Complete perforating. Start demobilization. 1/8/00 Saturday Tentative Plan Continue demobilization, dA~N 1/9/00 Sunday Tentative Plan Finish demobilization. 1/05/00 Time Operation 1400 Ru DS #15D9436, 14,351' of tapered 1-3/4" (ctv 31.5 bbls). Spot crane. Change out injector pack-off. 1530 Stab injector onto well. 1600 Hold pre-job safety meeting with all ~;rews. 1630 With master shut, begin pumping hot diesel through coil and across tree taking returns through PTS to the flowback tank. 1725 Shut down at 55 bbls. Shut in at PTS. PT injector, BOP body, and lines to PTS to 4000 psig. 1735 Open master valve. Pressure up to PTS. SIWHP = 1365 psig. Bleeding down WHP to flowline pressure. Operation: Badami B1-28 Cleanout. Page: 2 Initial Well Status Whp lap 0ap GIp FIp Fit psi psi psi psi psi °F Shut In 1365 2200 200 n/a n/a Time Depth Rate Ctp Whp Stage Rate Tank Remarks ft bpm psi psi bbls rtns strap 1745 surf 0.30 840 600 0 Start RIH pumping hot diesel at minimum rate. 1800 65 0.30 555 400 9 Continue bleeding off WHP while RIH. 1810 300 0.30 360 230 12 Equalized w/flowline. Switch to flowback tank. 1830 1400 0.30 200 230 17 Continue pumping hot diesel 1840 1500 0.25 160 225 20/0 Switch to KCI. 1'855 2200 1.2 880 225 5 1300 Increase rate. 150 deg F KCI 1930 3700 1.0 485 215 47 RIH looking for restriction. 1934 3960 1.8 1200 215 52 13 Found restriction, increased rate, PUll 1942 3950 1.8 1300 220 67 Weight check- 8000#. 1950 3965 2.4 1900 215 80 Tag hard at 3965'. Increase rate. 2003 3980 1.8 1900 210 110/0 1600 Switch to Biozan. 2023 4080 1.6 4000 215 33 Broke through bridge. Biozan at nozzle. PUH jetting. 2025 4050 1.6 4000 210 35/0 Switch to KCL to displace Biozan sweep. 2029 3800 1.7 3870 210 6 29 PUH to 3800. Run back in hole. 2036 4100 ' 1.8 2785 210 18 RIH jettingto 4100. PUH. 2045 3800 2.0 2100 210 33 KCI at nozzle. Continue to reciprocate from 3800'-4100' 2100 3900 ' 2.3 2100 210 64 Biozan in returns. Very little solids. 2115 4100 2.1 1855 215 90 Continue RIHjetting. 2130 4150 2.0 1890 215 120 69 Stop RIH. Repair level wind. Continue RIH. 2140 4560 0 1890 215 140 Shut down, swap to vertical tank. Move vac to FB tank. 2154 4415 0.30 283 215 140 Begin pumpin9 KCL at minimum rate. 2220 4800 1.00 905 208 148 Increase rate, continue RIH. Levelwind problems. 2235 5500 0.60 450 210 163 Returns clean - seeing some diesel. Decrease rate to conserve KCl. Weight check- 12,000# 2315 7900 0.80 480 210 195 Returns are 100 % diesel. Weight check- 18,000# 2340 10000 0.60 140 210 212 Weight check- 21,500#. 2350 11300 0.90 320 2.10 222 Weight check- 24,300#. 2356 11450 1.0 520 210 230 Lost a lit'tie weight while passin9 by #1 GLM (11400- 11500) 2400 11620 1.0 475 210 235 PUH jetting past #1 GLM. 1/06/00 0003 11400 1.1 520 210 238 Run back in hole, looked better jetting past #1 GLM. 0023 12200 1.2 312 210 265 A little sticky 12200' to 12225'. Weight check 28,000#. 0043 12250 1.5 990 210 290/0 Switch to Biozan. Continue RIH jetting. 0100 13350 1.8 3930 210 33 Biozan at nozzle. Weight check- 30,000#. 0108 13600 1.8 3805 210 48 Weight check- 31,000#. 0122 13960 1.5 3715 210 72 End of reel ... really. 0134 14280* 1.8 4010 210 94/0 *Adjusted depth based on coil records. Switch to KCI. 0141 13960 1.0 10 Dowell triplex blew packing. 0144 13960 .7 13 Decrease rate. Operation: Badami B1-28 Cleanout. ' ..... Page: 3 0146 13960 0 15 Shutdown. Tighten gland. 0150 13960 1.5 15 Start pumping, still leaking. 0155 13960 1.5 2580 210 23 Circulating on bottom. 0203 13960 0 780 210 33 KCI at nozzle. Shut down to switch to HB&R pump. 0209 13960 1.0 1700 210 39 Start pumping with HB&R 0220 13960 1.5 1730 210 55 Start POH. POll at80%. 0400 4500 1.5 1675 210 210 Returns 90% KCI, remainder diesel/oil, trace Biozan 0408 3700 1.5 1610 210 222 End KCI. 0414 3700 1.4 1660 210 0 Start diesel. 0437 3700 1.4 2220 210 32 Diesel at nozzle. Start POH laying in diesel. Returns showing gelled mud? 0501 1525 0 315 210 65 End diesel. Out of fluids. 0505 1525 0 Switch to N2. Displace remaining diesel out coil. Returns showing diesel cut and some gel. Time Operation 0530 At surface. Purge PTS with N2. 0600 Shut down N2. Blow down lines. 0630 Lay down injector and BOP's. 0700 Secure well. Well is shut in. ,Current Well Status Whp. lap Oap GIp FIp Fit' .. psi psi psi psi psi °F - Shut In 600 1000 200 : na na Fluid Summary Bbls Description 120 Diesel 622 2% KCI water 129 Biozan gel I\IL, 10 MeOH. N2 (18,624scf used for blow down ) JA 4" 881 Total ...... .,,.:: 0il & ~s Jet Swirl Nozzle Bottom Hole Assembly # 1 Tool String Descriptions O.D. I.D. Length Comments DS ct connector. 2.00 0 DS dual check valves. 2.00 1.00 0.94 Jet swirl nozzle 3.00 0.50 7 down, 4 around swirl. Total Length 1.44 WELL N°: B1-28 Additional Perforations BP EXPLORATION REP: Powers SERVICE COMPANY: Atlas/HB&R DATE/TIME OPERATIONS SUMMARY 1/06/00 Slickline tagged TD at 14,019'uncorrected depth. Convert unit to E-line operations for perforating. 20:30 PU gun # 1 (20' 2.75" predator 6 spf) and RIH. OAP=100, lAP=950, WHP=600. 23:21 Tie-in to fax from town. Tag PBTD at 14,037' ELMD. 11/7/00 00:15 Bleed Whp from 1200 psig to 600 psig and shoot gun from 14,015' -14,035' 3:00 At surface. Lay down equipment for night. SIWHP=1000 psig. 1/7/00 E-line engineer sent to Endicott for medical reasons. 1/8/00 13:00 Engineer back at Badami. Begin RU. 14:00 RIH with Gun #2 (20' 2.75" predator 6 spf). SIWHP=1200, IAP=1000 psig, OAP--100 psig. 14:45 Gun sat down at .-.200'. PUH to check tools and find stranded line. Gun stuck in lubricator across the tree. 17:00 Conduct pre-job safety meetings. I 17:30 Flow well into flow back tank. Open lubricator drain valves to check for pressure. Break quick connect, pull gun from tree and close master valve. 19:00 Safe gun out and remove from lubricator. BH 20 bbls of diesel down tubing. Initial pressure was 400 psig which steadily climbed to 3500 psig during displacement. Leave well SI for night. 1/9/00 0740 RIH with Gun #2 (20' 2.75" predator 6 spf). SIWHP-1200, IAP=1000 psig, OAP=100 psig. 10:20 Begin tie-in pass. GR shorted out. POOH to fix tool. 14:30 RIH with Gun #2 (20' 2.75" predator 6 spf). SIWHP=1200, IAP=1000 psig, OAP--100 psig. 15:10 Line shorted out at 2000'. POOH to re-head. 17:30 RIH with Gun #2 (20' 2.75" predator 6 spf). SIWHP--1200, IAP=1000 psig, OAP=100 psig. 19:40 Begin tie-in pass. Tag TD at 13,991'. PUH to shoot upper zone. 20:15 Bleed WHP from 1200 psig to 500 psig and shoot gun from 13,752' - 13,772'. 23:15 RIH with gun #3 ( 2 - 10', 2.75" predators @ 6 spf, select fire) 1:00 Line shorted out @ --- 12,000'. POOH to re-head. 3:30 RIH with gun #3 ( 2 - 10', 2.75" predators @ 6 spf, select fire) 5:30 Line shorted out @ ~- 12,200'. POOH to re-head. 7:00 At surface - toolstring and gun is missing. Appears that the line broke inside the cable head. Should have a clean fishing neck looking up. 7:30 BFI 10 bbls of Methanol down tubing. Final pumping pressure = 3500 psig. 1/10/0020:00 RIH with slickline toolstring, 3.625" bell guide and 2" pulling tool. SIWHP=1200 psig. 22:00 Sat down on liner hanger 11,820'. Can't work past, POOH to change toolstring. 1/11/00 1:00 RIH with 2.9" bell guide and 3.00" centralizer with pulling tool and knuckle joints. 3:30 Sitting down in same spot. Can't work past. POOH. 5:30 RBFN. (Fly over more centralizers and fishing tools) 1/12/0014:00 RIH with 2.9" bell guide and 3.625 centralizer with knuckle joints and 2" pulling tool. 16:45 Sat down at 13,870'. Unable to latch gun. POOH. 20:10 At surface. Pulling tool is full of mud. Convert unit to slickline for bailing. 1/13/00 2:00 RIH with 3" bailer 4:30 Sit down at 13, 842' and begin bailing. 6:30 At surface with bailer full of drilling mud. Appears that upper lateral is flowing mud into the slotted liner. Send Engineer out for medical attention and confer with town. 1/14/0014:00 MIRU. Convert unit to E-line 18:00 RIH with gun//3 ( 2 - 10', 2.75" predators @ 6 spf, select fire) 20:30 Tie-in to fax from town. Add 14' and tag TD. SIWHP = 1280 psig. 20:50 tag TD at 13,864'. POOH and shot gun from 13,823' -13,8,33'. No underbalance per instructions from town. Log off. 21:10 Log into position for 2nd gun. . 21:20 Shoot gun from 13,800- 13,810'. Log off and POOH. 23:00 At surface. RDMO : 23:20 POP well with gaslift and methanol. Perforation Summary - Logs correlated to Sperry Sun MWD 13,752' - 13,772' 20' 13,800' - 13,810' 10' 13,823' - 13,833' 10' 14,015' - 14,035' 20' 2.75" Predator guns at 6 spf and random orientation BP EXPLORATION Memorandum To: Blair Wondzell fm: Bill Turnbull October 12, 1999 Re: 10-403 for perforations on Badami B1-28 Blair, Please find attached the 10-403 application for your approval for a perforating job on Badami B1-28 which we would like to carry out this weekend. If you have any questions regarding the program please give me a call. Regards, Senior Petroleum Engineer Eastern North Slope 564-4662 ORIGINAL STATE OF ALASKA ALASKA-~-IL AND GAS CONSERVATION co~MlSSlON APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Per[orate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3858' NSL, 5266' WEL, SEC. 9, T9N, R20E, UM At top of productive interval 3388' NSL, 160 EWL, SEC. 3, T9N, R20E, UM At effective depth 3740' NSL, 23' EWL, SEC. 3, T9N, R20E, UM At total depth 3740' NSL, 23' EWL, SEC. 3, T9N, R20E, UM 5. Type of well: [~ Development F-1 Exploratory I--I Stratigraphic i--]Service 6. Datum Elevation (DF or KB) KBE = 55.62' 7. Unit or Property Name Badami Unit 8. Well Number B1-28 9. Permit Number 98-130 10. APl Number 50-029-22899 11. Field and Pool Badami 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 14310 feet 10703 feet 14310 feet 10703 feet Length Size Structural Conductor 73' 20" Surface 5407' 9-5/8" Intermediate 12001' 7" Production Liner 2464' 4-1/2" Plugs (measured) Junk (measured) Cemented 260 sx Arcticset (Approx.) 2930 sx PF 'E', 360 sx Class 'G' 185 sx Class 'G' Uncemented Slotted Liner ORIGINAL MD TVD 115' 115' 5442' 4523' 12034' 8894' 11844'-14308' 8738'-10701' Perforation depth: measured 12075' - 14308' true vertical 10246' - 10701' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 at 11580' Packers and SSSV (type and measured depth) Baker S-3 Permanent Packer at 11542' 13. Attachments [~ Description summary of proposal [--] Detailed operations program F-] BOP sketch 14. Estimated date for commencing operation October 16, 1999 16. If proposal was verbally approved 15. Status of well classifications as: [~ Oil ~1 Gas I~ Suspended Service Date approved Badami Petroleum Engineer Prepared By Name/Number: Name of approver Contact Engineer Name/Number:, Anr~u,.E.be, 564-5230 17. I herebYsigned certify tha,,(t~~ng.~..~_~d(,~ correct to the best of my knowledge BilITurnbull ~ ~ Title Sr. Petroleum Engineer, ENS Commission Use Only Conditions of Approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test Subsequent form reeo~'&d 10- o'4e°"' 6 ORIGINAL SIGNED BY ¢ toe ,.,,~ ^ Robert N Chdstenson ¢ 9,e?~/~' Approved by order of the uommission ' ./.~, ~ Commissioner Form 10-403 Rev. 06/15/88 Anna Dube, 564-5230 Date IApproval No.30~ - ~,.O~¢2 Submit In Triplicate BP EXPLORATION Memorandum To: J. Powers/M. Warren October 11, 1999 fm: A.Dube Re: Perforate: Well B1-28 Well B 1-28 is a multilateral well completed with uncemented slotted liners across the reservoir intervals. The well never performed as well as predictions would have lead us to expect (see well test history). One of the possible reasons for this under-performance is formation damage caused by the drilling or completion fluids. The purpose of this operation is to attempt to increase the production rate from the well by perforating past the possible damaged zone in the lateral in which we retain access. Following completion of the running of the full gas lift design, please perforate the following intervals in B 1-28: 13752'-13772' MD 13800'-13810' MD 13823'-13833' MD 13995'-14035' MD Perforation should be with 2 ~A" guns, 6 spf, 60/180° phasing, Predator deep penetrating charges. Depth control will need to be by perforating gamma ray if available. Any questions, or comments may be directed to Anna Dube (x5230). A~ Gary Osbo~e ' Date xc: B 1-28 Well File attachments: copy of reference log completion diagram well test history FINAL MD 1'600 l 1.240 MD ,{ FEWD SYSTEM ] ROP RATE OF PENETRATION NGP NATURAL GAMMA PROBE DGR DUAL GAMMA RAY EWR4 ELECTROMAGNETIC WAVE RESISTIVITY Company : BP EXPLORATION (ALASKA), INC. Rig : NABORS 28E Well : B1-28 Field : BADAMI Country : USA ~ N= 70: 09:08.040 ~ W= 147: 05: 36. 323 ~! X=364025 63 'Y=5906425.00 ASP ~ 3858FSL 5266FEL S09 TOgN R20E Elev.: 0.00 55.62 ft Ab.Perm. Dat. Job No: AK-VC-80308 Permanent Datum : HSL Log Heas. From : RKB DrIg. Heas. From: RKB API Number : 50-029-22899-00 · Size ' '~:!-' < i n ) ' 12. 250 ,- l__.~_-°°° OTHER SERVICES Dir. Drilling Mudlogging Elev. KB 55.62 DF 54.12 GL 19.60 WD 0.00 Borehole Record Casing Record From ~ To End Inc. Size Weight From To (ft MD) (ft MD) (deg) (in) (lb/ft) (fi MD) (ft HD~ 115 5460 56.8 20.000 91.1 37 116 5460 12055 33.8 9.625 40.0 35 5445 12055 14310 32.5 7.000 29.0 33 12035 13788 13888 Kelly bushing to wellhead/GL (fi) 35.3 Wellhead to sea level (ft) 19.8 Conductor L-80 IBT Production Tubing HES 'HXO' Safety Valve Landing Nipple Surface Casing Camco KGB2LS 4 1/2' x 1' GLM Camco KGB2LS 4 1/2' x 1' GLM Camco KGB2LS 4 1/2' x 1 · GLM Camco KGB2LS 4 1/2" x 1' GLM Camco KGB2LS 4 1/2' x 1' GLM Camco KGB2LS 4 1/2' x 1· GLM Baker S-3 Permanent Packer HES 'X· Landing Nipple HES 'XN' Landing Nipple Wireline Entry Guide 7' x 4 1/2' Liner Hanger/Packer 7' Intermediate Casing Bottom 4.5' Solid Liner/Top 4.5' Slotted Kick ©ff Point Mid-pay (for GL design) Top 4-1/2' Slotted Liner- Hole #1 Top 4-1/2· Slotted Liner- Hole #2 Fish: 14.5' jet cutter & firing head 4-1/2' Slotted Liner - Hole #3 Date Rev by Comments ###~##. B.Tumbull Initial design ######. M. Sauve Corrected to actual drilling depths and tubing tally Well Test Plot WELL: B1-28/BADAMI Dates from 10/22/1998 to 10/05/1999 5000 ,~ N R I F 4000 3000 2000 1000 900 800 700 600 500 4OO 300 200 lOO 90 80 70 60 5o M ,~ M I I A R P ' ======================= :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :: r._% ~ ;..,! ~_,,,_ ~__ _ 5 .... -:' ....... 5-- -__----.ti ........ i ........ i ........ i ...... ":- t- ;;.;-.L,--/.~i;?-,;-:-~*e-~-,~.--~ .... : ........ :---~ .... : ........ : ........ : ...... :-:- ~_ ,,[: .*'.~,_'_,~i'.\: ./_, .~*. *.*Jr .'.**_*. *_ .~.**. :.. ~ ....... .... ' ~ _~_'*_','ff_ *.~_ ~~~.._ ~'=..~_ _*_*_# ' t '. _**.: 'i""~--~ ,h 1~. .... I //I'' t~' ,~ ' ~ ' ~', ',~ I ~ : ', : ', ,( I', ~ ,, ~ : ,-* \ ', . ', / ', ' ' I~ / .... ~ ~, /i'~ ~ I/'/ ~ ' ~ ' / ~ ' . . :.~, . ~... :~; .......... ~, .... ; ....... ;.. ....... : ........ : .... -,1~ . .~-:-~. -Ii - - -; .... -~ .... : ..... e-;: - - - :~' - -; - --~-~-~--- ~---$~--- ~- ~- - - -, ....... ,- ........ , ........ ,---~¥ ~-~,-~,~,~-!:~':-;-~-~-- :--:: :~:~:~ ~t -~f~ · ~ - !: ~1:-.- - ...... : ..... I I ::::::-::~:i: I ": .... ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :'-::~: .--, ........ . .... r--~¥*---*-. ....... ~ ........ , ........ ,---!, .... ,---~I---, ...... ~,--. ........ :-~--~,---:- , ,~ ' I' ' ' ' ' ' ' ' ' \ ' ' ' " ~ ' "': ...... ~ '~, .... /I ............ ] ....... f ........ : ...... '-:-" ~,l ..... : ..... ii": ....... :-', .... i- ~ ':i-I' ' I - ' - ~,' "-: ........ ~ .... ii ............ :, ....... ~ ........ : ........ :----',l ..... : ..... It--: ....... :.-: .... ;-!-i-I--1--- ~- , , , i i i i i i i ,{ _ O N D J F M A M J J A S O 1998 1999 80 - 60 40 - - ~ ................. ~ 20 - - ' ........................................................ ' ......................... ' ......... , ~ O N D J F M A M J J A S O 1998 1999 October 12 1999 OPE V1.1.2,5 '"'-"7--1G ross Fluid '---E~'---IOil Rate IG.O.R. [Gas Lift IMam Pressure IMam Temp. . .~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG HOLE #3 1. Status of Well Classification of Service Well [~Oil I--I Gas [~] Suspended I--I Abandoned I~Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 98-130 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22899 4. Location of well at surface .... : ~ , ' '-- 9. Unit or Lease Name 3858' NSL, 5266' WEL, SEC. 9, T9N, R20E, UM ' ..... ~ - i Badami Unit At top of productive interval f,~/~.~/~'i~'~ ;- ~ 10. WellNumber 3388' NSL, 160 EWL, SEC. 3, TeN, R20E, UM .r,:~. ~;:_~ B1--28 At total depth . _ · 11. Field and Pool 3740' NSL, 23' EWL, SEC. 3, T9N, R20E, UM :: -. -- 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. I Badami KBE = 55.62'I ADL 365533 I 12. Date Spudded9/10/98 113' Date T'D' Reached I 14' Date C°mp" Susp/dr Aband'115' Water depth' if °ffsh°re 116' N°' °f c°mpletiOns9/19/98 10/18/98 -- I N/A MSL One 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD) 119. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 14310' 10703 FTI 14310' 10703 FTI [~Yes I~No 2191' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD/LWD 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO-R-OM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 37' 110' 24" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 35' 5442' 12-1/4" 2930 sx PF 'E', 360 Class 'G' 7" 29# Pl10 33' 12034' 8-1/2" 185 sx Class 'G' 4-1/2" 12.6# L-80 11844' 14308' 6" Uncemented slotted liner 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Liner 4-1/2", 12.6#, L-80 11580' 11541' MD TVD MD TVD 12075'- 14308' 10246'- 10701' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 140 bbls diesel KOP from B1-28L2 @ 12150' MD 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) October 22, 1998I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER-DEL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Top Badami Sands F3 13638' 10147' Top Badami Sands A5 14068' 10500' Base Badami Sands A5 14210' 10618' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the f~r..egoing is true and correct to the best of my knowledge I z. Signed~/1,4, ~...~ Mike E. Miller Title Badami Drilling Team Leader Date B1-28 98-130 Prepared By Name/Number: Carol Withey, 564-4114 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5.' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 -Well Complianc R p rt File on Left side of folder 198-130-0 BADAMI UNIT Roll #1: Start: Stop Roll #2: MI) !4_310 TYD 10730 Completion Date: B1-28 50- 029-22899-00 Start Stop 10/18/98 Completed Status: 1-OIL BP EXPLORATION (ALASKA) INC Current: Name Interval D 8852 6-8, 16 SPERRY MPT/GR/EWR4 OH L COMBOGAS-MD 1 12150-14310 OH 1 L COMBO GAS-TVD 1 8990-10703 OH 1 L NGP/DGR/EWR4-MD FINAL 5461-14310 OH L NGP/DGR/EWR4-TVD FINAL 4529-10703 OH R SRVY RPT SPERRY 12138.75-14310. OH Daily Well Ops .... Was the well cored? yes no Comments: Are Dry Ditch Samples Required? yesff Analysis Description Received? yes~ Sent Received T/C/I) 1/20/99 1/21/99 10/7/98 10/8/98 10/7/98 10/8/98 1/26/99 1/27/99 1/26/99 1/27/99 12/22/98 12/24/98 And Received? yes no Sample Set # Wednesday, November 08, 2000 Page 1 of 1 BP EXPLORATION, Alaska Date: 10-7-98 Trane# 89631 BADAMI OPEN HOLE LOG DATA Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 Trane Num Sw Name Log Type Rec Date Company Code Run Num Api Num 89631 B1-28L1 MUDLOG 24-Aug-98 SPERRY 500292289960 89631 B1-28 MUDLOG 19-Sep-98 SPERRY 500292289900 89631 B1-28L2 MUDLOG 08-Sep-98 SPERRY 500292289961 89631 B1-28L2 MUDLOG 08-Sep-98 SPERRY ~500292289961 89631 B1-28L1 MUDLOG 24-Aug-98 SPERRY 500292289960 89631 B1-28 MUDLOG 19-Sep-98 SPERRY 500292289900 Please sign and return one copy of this transmittal to: Carla Harris Petrotechnical Data Center LOG DATA AOGCC - 1 blueline/1 sepia PETROFINA- 1 blueline/1 sepia DNR - 1 blueline BP - - 1 blueline Howard Oakland Mike Engle Tim Rhyherd Evelyn Raybon OCT 07 1998 ~aska 0ii & Gas ~ns. C0mm~i~ Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 Facility Badami CPF Progress Report Well B 1-28 Rig Nabors 28E Page 7 Date 22 December 98 Date/Time 04 Sep 98 05 Sep 98 06 Sep 98 07 Sep 98 08 Sep 98 09 Sep 98 10 Sep 98 11 Sep 98 Duration Activity 09:00-09:30 1/2 hr N, Serviced Wear bushing 09:30-13:30 4 hr Nx Tested BOP stack 13:30-14:00 -N1/2 hr '"x, Serviced Wear bushing 14:00-14:30 Xld,2 hr R~¢oved Kelly/top drive hose 14:30-17:00 2-~')2 hr Ma'~'bqj. p BHA no. 12 17:00-21:30 4-1/2'h'~., R.I.H. to~'M,~40.0 ft 21:30-23:00 1-1/2 hr ""N Serviced Blo-Z,k~line 23:00-00:30 1-1/2 hr "N.~,x Rigged up KellyTto~drive hose 00:30-01:15 ',3../4 hr ,, R.I.H. to 12294.0 ft 01:15-03:30 2-"1./,4 hr xN~,Took MWD survey at l~g~.0 ft 03:30-06:00 2-1/2'hr D~led to 12638.0 ft 06:00-06:00 24 hr ""-,,,,~ Drill~dxto 13030.0 ft 06:00-06:00 24 hr --,~ Drilled'to~ 13505.0 ft 06:00-16:00 10 hr 'x-x, Drilled to"ix3,773.0 ft 16:00~16:30 1/2 hr s"xN1Circu!ated at'~o,7x73.0 ft 16:30-1~8:00 1-1/2 hr x,P~ulled out of hole"Sq,12318.0 ft 18:00-19:00'-., 1 hr R.~. to 13773.0 ft 19:00-06:00 ' '-,,, 11 hr Dd!_le _'~o 14070.0 ft 06:00-06:00 ' ""2.~,hr Drilled tbd,,4771.0 ft (cont...')X' 06:00-07:00 1 hi',,, Drilled to 1~,10.0 ft 07:00-09:30 2-1/2~'~..x Circulated at l~xl0.0 ft ' 09:30-10:45 1-1/4 hr "--. Pulled out of hole'to 13350 0 ft 10:45-12:00 1-1/4 hr "Nx R.I.H. to 14810.0 ftC- -' 12:00-14:30 2-1/2 hr Nx Circulated at_ 14810.0 ft 1~':30-16:30 2 hr XNPulled out of hole to 12381.B,4~ 16:30'-'17:00 1/2 hr 1S~culated at 12381.0 ft 17:00-~'~:-30 2-1/2 hr Cir0u~tedt oatf ~2o~e3~01 f2t360_0 ft 19:30-21:0~-,~ 1-1/2 hr Pulled'bo~ of hole to 12360.0 ft 21:00-21:45 ':'-'",~, 3/4 hr Pulled out, hole to 12000.0 ft 21:45-03:30 "~',5c3/4 hr Pulled out of'hqle to 657.0 ft 03:30-05:15 1-'31~ hr Pulled BHA NN '0,5:15-05:30 1/4 h't'N, Rigged up Casing h~,~,ling equipment 0~':h0-06:00 1/2 hr Xx Ran Liner to 700.0 ft (4x4,/2in OD) 06:00~.!3:00 7 hr "N~ RanLiner to 14810.0 ft (4-X142in OD) 13:00-1"5.~0 2-1/2 hr NX Circulated at 14144.0 ft 15:30-17:~0x 1-1/2 hr x, Circulated at 14144.0 ft 17:00-22:45 '~'x, 5-3/4 hr N.. Pulled Drillpipe in stands to 5133.0 ft 22:45-00:00 "'"-.,1-1/4 hr XK%n Drillpipe in stands to 7737.0 ft 0~'00-02:00 2"1tr LaiXckdown 2604.0 ft of Drillpipe 02:0~-05:00 3 hr x Pulle~Xt~rillpipe in stands to 0.0 ft 05.'00-~)fi: 15 1/4 hr""", Serviced~r bushing 05:15-06:x0Q, 3/4 hr "N Tested BOP~ck 06:00-08:45~ 2-3/4 hr '~',,, Tested BOP sta'bl~ 08:45-09:00 ~ 1/4 hr "-,. Installed Wear bus'tdng 09:00-11:00 "~r NNN1Made up BHA no. 13 11:00-15:30 4- l'/¢xhr ~.I.H. to 12129.0 ft 15:30-17:00 1-1/21K ~'ook MW_D s~_ur_v_e~ at 12129.0 ft 17:00-06:00 13 hr 06:00-12:15 6-1/4 hr 12:15-12:45 1/2 hr 12:45-13:00 1/4 hr 13:00-20:00 7 hr 20:00-21:15 1-1/4 hr 21:15-22:30 1-1/4 hr Drilled to 12169.0 ft Drilled to 12185.0 ft Circulated at 12185.0 ft Flow check Pulled out of hole to 633.0 ft Pulled BHA Made up BHA no. 14 Facility Date/Time 12 Sep 98 13 Sep 98 14 Sep 98 15 Sep 98 16 Sep 98 17 Sep 98 18 Sep 98 19 Sep 98 20 Sep 98 21 Sep 98 Progress Report Badami CPF Well B 1-28 Rig Nabors 28E Page 8 Date 22 December 98 22:30-05:00 05:00-05:45 05:45-06:00 06:00-07:00 07:00-06:00 06:00-03:00 03:00-03:15 03:15-03:30 03:30-06:00 06:00-09:00 09:00-10:15 10:15-13:00 13:00-18:00 18:00-18:45 18:45-21:00 21:00-21:15 21:15-06:00 06:00-06:00 06:00-06:00 06:00-06:00 06:00-06:00 06:00-11:45 11:45-13:00 13:00-13:15 13:15-14:30 14:30-16:00 16:00-16:30 16:30-16:45 16:45-17:30 17:30-19:30 19:30-20:00 20:00-21:30 21:30-22:00 22:00-22:15 22:15-03:30 03:30-03:45 03:45-05:00 05:00-06:00 06:00-06:30 06:30-06:45 06:45-12:00 12:00-13:00 13:00-17:15 17:15-18:00 18:00-19:15 19:15-19:30 19:30-22:00 22:00-00:00 00:00-01:45 01:45-02:15 02:15-06:00 06:00-10:45 10:45-11:00 Duration 6-1/2 hr 3/4 hr 1/4 hr 1 hr 23 hr 21hr 1/4 hr 1/4 hr 2-1/2 hr 3 hr 1-1/4 hr 2-3/4 hr 5 hr 3/4 hr 2-1/4 hr 1/4 hr 8-3/4 hr 24 hr 24 hr 24 hr 24 hr 5-3/4 hr 1-1/4 hr 1/4 hr 1-1/4 hr 1-1/2 hr 1/2 hr 1/4 hr 3/4 hr 2 hr 1/2 hr 1-1/2 hr 1/2 hr 1/4 hr 5-1/4 hr 1/4 hr 1-1/4 hr 1 hr 1/2 hr 1/4 hr 5-1/4 hr 1 hr 4-1/4 hr 3/4 hr 1-1/4 hr 1/4 hr 2-1/2 hr 2 hr 1-3/4 hr 1/2 hr 3-3/4 hr 4-3/4 hr 1/4 hr Activity R.I.H. to 12034.0 ft Serviced Block line Took MWD survey at 12124.0 ft Washed to 12185.0 ft Drilled to 12420.0 ft Drilled to 12556.0 ft (cont...) Circulated at 12556.0 ft Flow check Pulled out of hole to 8700.0 ft Pulled out of hole to 195.0 ft (cont...) Pulled BHA Made up BHA no. 14 R.I.H. to 12136.0 ft Functioned downhole tools at 12136.0 ft Logged hole with LWD: Formation evaluation (FE) from 12151.0 ft to 12556.0 ft Functioned downhole tools at 12534.0 ft Drilled to 12735.0 ft Drilled to 13045.0 ft Drilled to 13400.0 ft Drilled to 13860.0 ft Drilled to 14250.0 ft Drilled to 14310.0 ft Circulated at 14310.0 ft Flow check Pulled out of hole to 12245.0 ft Pumped out of hole to 12183.0 ft Pulled out of hole to 11999.0 ft Flow check R.I.H. to 14310.0 ft Circulated at 14310.0 ft Circulated at 14310.0 ft Laid down 1825.0 ft of 4in OD drill pipe Pulled out of hole to 11999.0 ft Flow check Pulled out of hole to 632.0 ft Flow check Pulled BHA Downloaded MWD tool Rigged up Casing handling equipment Held safety meeting Ran Liner to 2232.0 ft (4-1/2in OD) Installed Liner hanger Ran Drillpipe in stands to 11989.0 ft Circulated at 11989.0 ft Ran Drillpipe in stands to 14310.0 ft Installed Circulating head Functioned Liner hanger Circulated at 11883.0 ft Laid down 1000.0 ft of Drillpipe Serviced Kelly Laid down 4425.0 ft of Drillpipe Laid down 6418.0 ft of 3-1/2in OD drill pipe Rigged down sub-surface equipment - Liner hanger Facility Date/Time 22 Sep 98 23 Sep 98 24 Sep 98 Progress Report B adami CPF Well B 1-28 Page 9 Rig Nabors 28E Date 17 December 98 11:00-11:30 11:30-12:00 12:00-12:30 12:30-13:45 13:45-16:45 16:45-17:00 17:00-20:00 20:00-20:15 20:15-23:45 23:45-00:00 00:00-02:30 02:30-03:30 03:30-06:00 06:00-07:45 07:45-09:00 09:00-10:15 10:15-12:00 12:00-14:00 14:00-15:00 15:00-20:00 20:00-02:30 02:30-04:30 04:30-06:00 06:00-06:30 06:30-06:45 06:45-08:00 08:00-08:15 08:15-09:30 09:30-10:30 10:30-11:00 11:00-12:30 12:30-13:15 13:15-15:15 15:15-15:30 15:30-17:00 17:00-18:00 18:00-18:30 18:30-19:15 19:15-20:00 20:00-20:15 20:15-20:30 20:30-21:00 21:00-21:30 21:30-22:30 22:30-00:45 00:45-02:00 02:00-03:00 03:00-04:45 04:45-06:00 06:00-07:15 07:15-08:00 08:00-09:30 09:30-12:15 12:15-16:00 Duration 1/2 hr 1/2 hr 1/2 hr 1-1/4 hr 3 hr 1/4 hr 3 hr 1/4 hr 3-1/2 hr 1/4 hr 2-1/2 hr 1 hr 2-1/2 hr 1-3/4 hr 1-1/4 hr 1-1/4 hr 1-3/4 hr 2 hr 1 hr 5 hr 6-1/2 hr 2 hr 1-1/2 hr 1/2 hr 1/4 hr 1-1/4 hr 1/4 hr 1-1/4 hr 1 hr 1/2 hr 1-1/2 hr 3/4 hr 2 hr 1/4 hr 1-1/2 hr 1 hr 1/2 hr 3/4 hr 3/4 hr 1/4 hr 1/4 hr 1/2 hr 1/2 hr 1 hr 2-1/4 hr 1-1/4 hr 1 hr 1-3/4 hr 1-1/4 hr 1-1/4 hr 3/4 hr 1-1/2 hr 2-3/4 hr 3-3/4 hr Activity Retrieved Wear bushing Installed Completion string handling equipment Held safety meeting Installed Hydraulic packer Ran Tubing to 1695.0 ft (4-1/2in OD) Circulated at 1695.0 ft Ran Tubing to 4939.0 ft (4-1/2in OD) Circulated at 4939.0 ft Ran Tubing to 7100.0 ft (4-1/2in OD) Held safety meeting Ran Tubing to 9450.0 ft (4-1/2in OD) Installed SCSSSV nipple assembly Ran Tubing to 10809.0 ft (4-1/2in OD) Ran Tubing to 11725.0 ft (4-1/2in OD) Installed SCSSSV control line Ran Tubing on landing string to 11725.0 ft Rigged down Tubing handling equipment Serviced BOP stack Serviced Block line Serviced BOP stack Rigged down BOP stack Installed All tree valves Tested All tree valves Retrieved Hanger plug Held safety meeting Installed Chicksan lines Held safety meeting Installed Slickline unit Held safety meeting Tested Lubricator Held safety meeting Held safety meeting Tested Chicksan lines Tested Chicksan lines Circulated at 11725.0 ft Installed Standing valve Functioned Hydraulic packer Tested Hydraulic packer Tested Tubing - Via string Tested Permanent packer - Via annulus Tested Chicksan lines Tested Tubing - Via string Tested Permanent packer - Via annulus Conducted slickline operations on Slickline equipment - Tool run Monitor pressures Conducted slickline Conducted slickline Conducted slickline Conducted slickline Conducted slickline Monitor pressures Conducted slickline Conducted slickline Monitor pressures operations on Slickline equipment - Retrival run operations on Slickline equipment - Retrival run operations on Slickline equipment - Tool run operations on Slickline equipment - Tool run operations on Slickline equipment - Retrival run operations on Slickline equipment - Setting run operations on Slickline equipment - Setting run Facility Date/Time 25 Sep 98 26 Sep 98 27 Sep 98 Progress Report Badami CPF Well B1-28 Page 10 Rig Nabors 28E Date 17 December 98 16:00-16:30 16:30-16:45 16:45-17:00 17:00-17:15 17:15-17:45 17:45-18:00 18:00-18:30 18:30-20:00 20:00-20:15 20:15-00:00 00:00-01:30 01:30-03:45 03:45-06:00 06:00-07:45 07:45-09:45 09:45-10:00 10:00-10:15 10:15-10:45 10:45-11:15 11:15-14:00 14:00-14:45 14:45-15:30 15:30-22:30 22:30-00:30 00:30-03:30 03:30-05:00 05:00-05:15 05:15-06:00 06:00-06:30 06:30-07:00 07:00-07:15 07:15-07:30 07:30-07:45 07:45-08:00 08:00-12:00 12:00-15:30 15:30-17:00 17:00-18:00 18:00-18:15 18:15-19:00 19:00-21:30 21:30-21:45 21:45-00:00 00:00-00:15 00:15-02:00 02:00-05:30 05:30-06:00 06:00-08:30 08:30-09:45 09:45-12:30 12:30-12:45 12:45-15:30 15:30-18:15 18:15-21:45 Duration 1/2 hr 1/4 hr 1/4 hr 1/4 hr 1/2 hr 1/4 hr 1/2 hr 1-1/2 hr 1/4 hr 3-3/4 hr 1-1/2 hr 2-1/4 hr 2-1/4 hr 1-3/4 hr 2 hr 1/4 hr 1/4 hr 1/2 hr 1/2 hr 2-3/4 hr 3/4 hr 3/4 hr 7 hr 2 hr 3 hr 1-1/2 hr 1/4 hr 3/4 hr 1/2 hr 1/2 hr 1/4 hr 1/4 hr 1/4 hr 1/4 hr 4 hr 3-1/2 hr 1-1/2 hr 1 hr 1/4 hr 3/4 hr 2-1/2 hr 1/4 hr 2-1/4 hr 1/4 hr 1-3/4 hr 3-1/2 hr 1/2 hr 2-1/2 hr 1-1/4 hr 2-3/4 hr 1/4 hr 2-3/4 hr 2-3/4 hr 3-1/2 hr Activity Tested Tubing - Via string Tested Permanent packer - Via annulus Tested Permanent packer - Via annulus Tested Permanent packer - Via annulus Tested Permanent packer - Via annulus Tested Permanent packer - Via annulus Tested Permanent packer - Via annulus Tested Permanent packer - Via annulus Bleed down well Monitor pressures Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Setting run Conducted slickline operations on Slickline equipment - Setting run (con Conducted slickline operations on Slickline equipment - Setting run Held safety meeting Tested Chicksan lines Tested Tubing Tested Tubing Conducted slickline operations on Slickline equipment - Retrival run Held safety meeting Held safety meeting Circulated at 11607.0 ft Monitor pressures Conducted slickline operations on Slickline equipment - Setting run Conducted slickline operations on Slickline equipment - Setting run Held safety meeting Tested Tubing Tested Tubing Bleed down well Tested Casing - Via annulus Tested Casing - Via annulus Tested Casing - Via annulus Tested Casing - Via annulus Tested Casing - Via annulus Bleed down well Tested Casing Monitor pressures Held safety meeting Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Retrival run Held safety meeting Circulated at 11607.0 ft Held safety meeting Conducted slickline operations Conducted slickline operations Conducted slickline operations Conducted slickline operations Serviced Slickline unit Conducted slickline operations Conducted slickline operations Conducted slickline operations Conducted slickline operations Conducted slickline operations on Slickline equipment - Retrival run on Slickline equipment - Retrival run on Slickline equipment - Retrival run on Slickline equipment - Retrival run on Slickline equipment - Retrival run on Slickline equipment - Retrival run on Slickline equipment - Setting run on Slickline equipment - Retrival run on Slickline equipment - Retrival run ...) Facility Date/Time 28 Sep 98 29 Sep 98 30 Sep 98 01 Oct 98 Progress Report Badami CPF Well B 1-28 Page 11 Rig Nabors 28E Date 17 December 98 21:45-22:15 22:15-23:30 23:30-01:45 01:45-04:30 04:30-05:00 05:00-05:15 05:15-05:30 05:30-06:00 06:00-09:15 09:15-09:30 09:30-10:15 10:15-11:00 11:00-12:00 12:00-15:00 15:00-19:30 19:30-21:00 21:00-00:00 00:00-01:30 01:30-04:00 04:00-04:30 04:30-05:00 05:00-06:00 06:00-06:15 06:15-07:00 07:00-07:30 07:30-12:45 12:45-14:30 14:30-20:00 20:00-22:15 22:15-00:00 00:00-00:30 00:30-01:30 01:30-03:00 03:00-03:30 03:30-06:00 06:00-08:00 08:00-08:30 08:30-10:00 10:00-12:00 12:00-18:30 18:30-20:45 20:45-21:30 21:30-06:00 06:00-06:30 06:30-08:00 08:00-12:15 12:15-13:00 13:00-14:45 14:45-15:15 15:15-15:30 15:30-16:30 16:30-19:00 19:00-20:30 20:30-21:00 Duration 1/2 hr 1-1/4 hr 2-1/4 hr 2-3/4 hr 1/2 hr 1/4 hr 1/4 hr 1/2 hr 3-1/4 hr 1/4 hr 3/4 hr 3/4 hr 1 hr 3 hr 4-1/2 hr 1-1/2 hr 3 hr 1-1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 1 hr 1/4 hr 3/4 hr 1/2 hr 5-1/4 hr 1-3/4 hr 5-1/2 hr 2-1/4 hr 1-3/4 hr 1/2 hr 1 hr 1-1/2 hr 1/2 hr 2-1/2 hr 2 hr 1/2 hr 1-1/2 hr 2 hr 6-1/2 hr 2-1/4 hr 3/4 hr 8-1/2 hr 1/2 hr 1-1/2 hr 4-1/4 hr 3/4 hr 1-3/4 hr 1/2 hr 1/4 hr 1 hr 2-1/2 hr 1-1/2 hr 1/2 hr Activity Rigged down sub-surface equipment - Slickline / braided cable Held safety meeting Rigged up sub-surface equipment - Slickline / braided cable Conducted electric cable operations Rigged down sub-surface equipment - Slickline / braided cable Held safety meeting Rigged up Fluid system Circulated at 11607.0 ft Circulated at 11607.0 ft Flow check Installed Accessories Rigged down Accessories Rigged down Xmas tree Rigged up BOP stack Serviced Pipe ram Installed Flowline Tested BOP stack Serviced Blind ram Tested BOP stack Rigged down BOP test plug assembly Rigged up Tubing handling equipment Rigged up Well control Removed Lubricator Rigged up Tubing handling equipment Rigged up Tubing hanger Worked stuck pipe at 11640.0 ft Rigged up Lubricator Conducted electric cable operations Circulated at 11607.0 ft Reverse circulated at 11607.0 ft Circulated at 11607.0 ft Rigged up Tubing handling equipment Reverse circulated at 11607.0 ft Circulated at 11607.0 ft Cleared Circulating head Flow check Circulated at 11607.0 ft Retrieved Tubing hanger Rigged up Slickline unit Laid down 2277.0 ft of Tubing Rigged up Slickline unit Conducted slickline operations on Slickline equipment - Retrival run Laid down 4155.0 ft of Tubing Laid down 292.0 ft of Tubing Conducted slickline operations on Slickline equipment - Retrival run Laid down 3533.0 ft of Tubing Conducted slickline operations on Slickline equipment - Retrival run Laid down 1150.0 ft of Tubing Conducted slickline operations on Slickline equipment - Retrival run Laid down 240.0 ft of Tubing Rigged down Tubing handling equipment Rigged up Drillstring handling equipment Circulated at 20.0 ft Installed Well control Facility Date/Time 02 Oct 98 03 Oct 98 04 Oct 98 05 Oct 98 Badami CPF Progress Report Well B 1-28 Rig Nabors 28E Page Date Duration Activity 21:00-22:00 22:00-06:00 06:00-09:30 09:30-12:00 12:00-17:00 17:00-18:00 18:00-19:00 19:00-00:30 00:30-00:45 00:45-01:30 01:30-02:30 02:30-03:15 03:15-04:00 04:00-06:00 06:00-09:00 09:00-09:15 09:15-09:45 09:45-15:00 15:00-17:30 17:30-19:30 19:30-21:30 21:30-22:00 22:00-22:30 22:30-00:00 00:00-00:30 00:30-01:15 01:15-01:45 01:45-03:00 03:00-03:15 03:15-04:30 04:30-04:45 04:45-05:30 05:30-05:45 05:45-06:00 06:00-06:15 06:15-07:15 07:15-09:00 09:00-09:15 09:15-10:30 10:30-11:00 11:00-11:30 11:30-13:00 13:00-13:45 13:45-14:45 14:45-16:00 16:00-17:00 17:00-20:00 20:00-22:45 22:45-00:00 00:00-02:00 02:00-03:00 03:00-04:15 04:15-04:45 04:45-06:00 1 hr 8 hr 3-1/2 hr 2-1/2 hr 5 hr 1 hr 1 hr 5-1/2 hr 1/4 hr 3/4 hr 1 hr 3/4 hr 3/4 hr 2 hr 3 hr 1/4 hr 1/2 hr 5-1/4 hr 2-1/2 hr 2 hr 2 hr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 3/4 hr 1/2 hr 1-1/4 hr 1/4 hr 1-1/4 hr 1/4 hr 3/4 hr 1/4 hr 1/4 hr 1/4 hr 1 hr 1-3/4 hr 1/4 hr 1-1/4 hr 1/2 hr 1/2 hr 1-1/2 hr 3/4 hr 1 hr 1-1/4 hr 1 hr 3 hr 2-3/4 hr 1-1/4 hr 2 hr 1 hr 1-1/4 hr 1/2 hr 1-1/4 hr Made up BHA no. 16 R.I.H. to 7300.0 ft R.I.H. to 11522.0 ft Washed to 11642.0 ft Pulled out of hole to 921.0 ft Pulled BHA Made up BHA no. 17 R.I.H. to 11590.0 ft Held safety meeting Set Bridge plug at 11627.0 ft with 2000.0 psi Tested Casing - Via annulus and string Circulated at 11590.0 ft Laid down 10.0 ft of 4in OD drill pipe Pulled out of hole to 7600.0 ft Pulled out of hole to 921.0 ft Pulled BHA Made up BHA no. 18 R.I.H. to 5500.0 ft Tested Casing - Via string Pulled out of hole to 2529.0 ft Tested Casing - Via string Circulated at 2517.0 ft R.I.H. to 2813.0 ft Tested Casing - Via string Pulled out of hole to 1865.0 ft Tested Casing - Via string Pulled out of hole to 1016.0 ft Tested Casing - Via string R.I.H. to 1299.0 ft Tested Casing - Via string Pulled out of hole to 1205.0 ft Tested Casing - Via string Pulled out of hole to 1111.0 ft Tested Casing - Via annulus Tested Casing - Via annulus Tested Casing - Via annulus Tested Casing - Via string Circulated at 1194.0 ft Pulled out of hole to 0.0 ft Made up BHA no. 19 Rest hole at 0.0 ft R.I.H. to 1250.0 ft Cut Casing at 1250.0 ft Pulled out of hole to 0.0 ft Circulated at 1250.0 ft Removed Well control Laid down 1250.0 ft of Casing Made up BHA no. 20 R.I.H. to 1250.0 ft Functioned downhole tools at 1274.0 ft Pulled out of hole to 925.0 ft Serviced Setting tools Pulled BHA Made up BHA no. 21 12 17 December 98 Facility Date/Time 06 Oct 98 07 Oct 98 08 Oct 98 09 Oct 98 Badami CPF Progress Report Well B 1-28 Rig Nabors 28E Page Date 06:00-06:45 06:45-10:45 10:45-11:00 11:00-11:15 11:15-13:00 13:00-15:00 15:00-17:00 17:00-17:30 17:30-18:30 18:30-19:30 19:30-22:30 22:30-01:00 01:00-04:00 04:00-04:30 04:30-06:00 06:00-09:30 09:30-10:15 10:15-10:45 10:45-11:00 11:00-12:00 12:00-12:30 12:30-14:00 14:00-14:45 14:45-16:45 16:45-19:00 19:00-20:00 20:00-20:30 20:30-04:30 04:30-04:45 04:45-06:00 06:00-11:00 11:00-12:30 12:30-16:00 16:00-17:00 17:00-20:00 20:00-20:45 20:45-00:30 00:30-01:15 01:15-03:00 03:00-03:45 03:45-06:00 06:00-07:00 07:00-08:00 08:00-09:00 09:00-09:30 09:30-10:30 10:30-12:00 12:00-15:00 15:00-20:00 20:00-21:00 21:00-04:45 04:45-05:45 05:45-06:00 06:00-07:15 Duration 3/4 hr 4 hr 1/4 hr 1/4 hr 1-3/4 hr 2 hr 2 hr 1/2 hr 1 hr 1 hr 3 hr 2-1/2 hr 3 hr 1/2 hr 1-1/2 hr 3-1/2 hr 3/4 hr 1/2 hr 1/4 hr 1 hr 1/2 hr 1-1/2 hr 3/4 hr 2 hr 2-1/4 hr 1 hr 1/2 hr 8 hr 1/4 hr 1-1/4 hr 5 hr 1-1/2 hr 3-1/2 hr 1 hr 3 hr 3/4 hr 3-3/4 hr 3/4 hr 1-3/4 hr 3/4 hr 2-1/4 hr 1 hr 1 hr 1 hr 1/2 hr 1 hr 1-1/2 hr 3 hr 5 hr 1 hr 7-3/4 hr 1 hr 1/4 hr 1-1/4 hr Activity R.I.H. to 1209.0 ft Circulated at 1200.0 ft R.I.H. to 1250.0 ft Functioned downhole tools at 1252.0 ft Pulled out of hole to 0.0 ft Installed Casing handling equipment Ran Casing to 1275.0 ft (7in OD) Circulated at 1275.0 ft Ran Casing to 1275.0 ft (7in OD) Tested Tubular strings - Via string Rigged up BOP stack Rigged up Seal assembly Installed BOP stack Removed Drillfloor / Derrick Tested BOP stack Tested All functions Installed Wear bushing Tested Casing - Via annulus Made up BHA no. 22 R.I.H. to 1550.0 ft Circulated at 1550.0 ft R.I.H. to 4500.0 ft Circulated at 4500.0 ft R.I.H. to 11595.0 ft Circulated at 11627.0 ft Functioned downhole tools at 11627.0 ft Circulated at 11627.0 ft Pulled out of hole to 12.0 ft Pulled BHA Made up BHA no. 23 R.I.H. to 11617.0 ft Serviced Block line Milled Tubing at 11651.0 ft Circulated at 11651.0 ft Milled Tubing at 11660.0 ft Circulated at 11660.0 ft Milled Tubing at 11671.0 ft Circulated at 11672.0 ft Milled Tubing at 11675.0 ft Circulated at 11675.0 ft Milled Tubing at 11682.0 ft Milled Tubing at 11685.0 ft Circulated at 11685.0 ft Milled Tubing at 11686.0 ft Washed to 11793.0 ft Circulated at 11793.0 ft Worked toolstring at 11793.0 ft Circulated at 11691.0 ft Circulated at 11793.0 ft Flow check Pulled out of hole to 921.0 ft Pulled BHA Made up BHA no. 24 Made up BHA no. 24 13 17 December 98 Facility Date/Time 10 Oct 98 11 Oct 98 12 Oct 98 13 Oct 98 Badami CPF Progress Report Well B 1-28 Rig Nabors 28E 07:15-09:00 09:00-09:30 09:30-10:15 10:15-11:00 11:00-12:00 12:00-12:30 12:30-14:00 14:00-15:00 15:00-15:45 15:45-04:00 04:00-05:30 05:30-06:00 06:00-06:30 06:30-07:15 07:15-07:30 07:30-08:30 08:30-09:00 09:00-11:00 11:00-12:15 12:15-22:00 22:00-01:00 01:00-01:15 01:15-02:00 02:00-02:15 02:15-03:15 03:15-05:00 05:00-05:30 05:30-06:00 06:00-06:45 06:45-07:00 07:00-07:30 07:30-10:45 10:45-18:30 18:30-18:45 18:45-20:30 20:30-21:30 21:30-22:00 22:00-02:30 02:30-03:30 03:30-03:45 03:45-06:00 06:00-10:15 10:15-12:15 12:15-16:30 16:30-18:30 18:30-22:00 22:00-01:45 01:45-04:15 04:15-06:00 06:00-12:00 12:00-18:15 18:15-18:30 18:30-21:30 21:30-21:45 Duration 1-3/4 hr 1/2 hr 3/4 hr 3/4 hr 1 hr 1/2 hr 1-1/2 hr 1 hr 3/4 hr 12-1/4 hr 1-1/2 hr 1/2 hr 1/2 hr 3/4 hr 1/4 hr 1 hr 1/2 hr 2 hr 1-1/4 hr 9-3/4 hr 3 hr 1/4 hr 3/4 hr 1/4 hr 1 hr 1-3/4 hr 1/2 hr 1/2 hr 3/4 hr 1/4 hr 1/2 hr 3-1/4 hr 7-3/4 hr 1/4 hr 1-3/4 hr 1 hr 1/2 hr 4-1/2 hr 1 hr 1/4 hr 2-1/4 hr 4-1/4 hr 2 hr 4-1/4 hr 2 hr 3-1/2 hr 3-3/4 hr 2-1/2 hr 1-3/4 hr 6 hr 6-1/4 hr 1/4 hr 3 hr 1/4 hr Activity R.I.H. to 4100.0 ft Circulated at 4100.0 ft R.I.H. to 6698.0 ft Circulated at 6698.0 ft R.I.H. to 8977.0 ft Circulated at 8977.0 ft R.I.H. to 11794.0 ft Circulated at 11794.0 ft Functioned downhole tools at 11794.0 ft Pulled out of hole to 963.0 ft Pulled BI-IA Made up BHA no. 25 Made up BI-IA no. 25 R.I.H. to 3790.0 ft Circulated at 3790.0 ft R.I.H. to 7564.0 ft Circulated at 7564.0 ft R.I.H. to 11798.0 ft Functioned downhole tools at 11821.0 ft Pulled out of hole to 962.0 ft Pulled BI-IA Removed Wear bushing Circulated at 25.0 ft Rigged up Wear bushing Made up BI-LA no. 26 R.I.H. to 7640.0 ft Circulated at 7640.0 ft R.I.H. to 8320.0 ft R.I.H. to 11660.0 ft (cont...) Circulated at 11660.0 ft R.I.H. to 11860.0 ft Circulated at 11860.0 ft Pulled out of hole to 975.0 ft Flow check Pulled BHA Serviced Block line Made up BI-IA no. 27 R.I.H. to 11860.0 ft Circulated at 11860.0 ft Flow check Pulled out of hole to 9000.0 ft Pulled out of hole to 950.0 ft (cont...) Pulled BI-IA Rigged down Top ram Made up BHA no. 28 Singled in drill pipe to 2602.0 ft R.I.H. to 11836.0 ft Washed to 12068.0 ft Circulated at 12112.0 ft Washed to 14308.0 ft Circulated at 14308.0 ft Flow check Pulled out of hole to 11836.0 ft Flow check Page Date 14 17 December 98 Facility Date/Time 14 Oct 98 15 Oct 98 16 Oct 98 17 Oct 98 Progress Report Badami CPF Well B 1-28 Page 15 Rig Nabors 28E Date 17 December 98 21:45-22:00 22:00-02:15 02:15-02:30 02:30-06:00 06:00-07:00 07:00-08:00 08:00-09:00 09:00-09:15 09:15-14:45 14:45-15:00 15:00-15:15 15:15-15:30 15:30-16:15 16:15-19:45 19:45-20:00 20:00-23:00 23:00-23:10 23:10-02:15 02:15-03:45 03:45-04:00 04:00-06:00 06:00-09:15 09:15-09:30 09:30-10:00 10:00-10:15 10:15-17:30 17:30-17:45 17:45-21:30 21:30-22:15 22:15-03:00 03:00-04:00 04:00-04:30 04:30-05:00 05:00-06:00 06:00-07:00 07:00-13:15 13:15-14:15 14:15-16:30 16:30-16:45 16:45-17:15 17:15-17:45 17:45-19:15 19:15-19:45 19:45-20:15 20:15-22:15 22:15-00:00 00:00-00:30 00:30-00:45 00:45-01:15 01:15-02:00 02:00-02:10 02:10-03:15 03:15-05:00 05:00-06:00 Duration 1/4 hr 4-1/4 hr 1/4 hr 3-1/2 hr 1 hr 1 hr 1 hr 1/4 hr 5-1/2 hr 1/4 hr 1/4 hr 1/4 hr 3/4 hr 3-1/2 hr 1/4 hr 3 hr 0 hr 3 hr 1-1/2 hr 1/4 hr 2 hr 3-1/4 hr 1/4 hr 1/2 hr 1/4 hr 7-1/4 hr 1/4 hr 3-3/4 hr 3/4 hr 4-3/4 hr 1 hr 1/2 hr 1/2 hr 1 hr 1 hr 6-1/4 hr lhr 2-1/4 hr 1/4 hr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 2 hr 1-3/4 hr 1/2 hr 1/4 hr 1/2 hr. 3/4 hr 0 hr lhr 1-3/4 hr 1 hr Activity Circulated at 11836.0 ft Pumped out of hole to 3540.0 ft Flow check Pulled out of hole to 1000.0 ft Pulled out of hole to 0.0 ft (cont...) Serviced Top ram Serviced Top ram Retrieved Wear bushing Tested BOP stack Rigged down Rig services Installed Wear bushing Held safety meeting Rigged up Logging/braided cable equipment Conducted electric cable operations Rigged down Wireline units Ran Drillpipe in stands to 6107.0 ft Held safety meeting Laid down 4247.0 ft of 4in OD drill pipe Ran Drillpipe in stands to 7760.0 ft Rigged down Kelly Laid down 5400.0 ft of 4in OD drill pipe Laid down 5400.0 ft of 4in OD drill pipe Removed Wear bushing Rigged up Casing handling equipment Held safety meeting Ran Tubing to 0.0 ft (4-1/2in OD) Flow check Ran Tubing to 9380.0 ft (4-1/2in OD) Tested Dual control line Ran Tubing to 11578.0 ft (4-1/2in OD) Installed Wellhead assembly Tested Hanger plug Rigged down Tubing handling equipment Rigged down Top ram Rigged down BOP handling equipment Removed BOP stack Rigged down Additional services Installed Xmas tree Tested Tubing bonnet Tested Xmas tree Retrieved Hanger plug Rigged up High pressure lines Held safety meeting Tested Lubricator Tested High pressure lines Circulated at 11.0 ft Held safety meeting Set Permanent packer at 11541.0 ft with 5600.0 psi Tested Tubing Tested Tubing Held safety meeting Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Retrival run Facility Date/Time 18 Oct 98 Progress Report Badami CPF Well B 1-28 Page 16 Rig Nabors 28E Date 17 December 98 06:00-07:00 07:00-09:30 09:30-12:15 12:15-14:00 14:00-15:00 15:00-15:15 15:15-15:45 15:45-16:00 16:00-19:30 19:30-20:00 20:00-21:00 21:00-22:15 22:15-00:00 00:00-01:30 01:30-03:00 03:00-05:00 05:00-06:00 06:00-06:30 06:30-06:45 06:45-07:00 07:00-07:45 07:45-08:30 08:30-09:00 09:00-09:15 09:15-09:30 09:30-10:00 10:00-12:00 12:00-14:00 14:00-14:30 14:30-15:00 15:00-15:15 15:15-15:30 15:30-16:00 16:00-17:00 Duration 1 hr 2-1/2 hr 2-3/4 hr 1-3/4 hr 1 hr 1/4 hr 1/2 hr 1/4 hr 3-1/2 hr 1/2 hr 1 hr 1-1/4 hr 1-3/4 hr 1-1/2 hr 1-1/2 hr 2 hr 1 hr 1/2 hr 1/4 hr 1/4 hr 3/4 hr 3/4 hr 1/2 hr 1/4 hr 1/4 hr 1/2 hr 2 hr 2 hr 1/2 hr 1/2 hr 1/4 hr 1/4 hr 1/2 hr 1 hr Activity Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Setting run Conducted slickline operations on Slickline equipment - Setting run Cleared Chicksan lines Held safety meeting Tested Nipple plug - Via string Functioned Other sub-surface equipment Circulated at 11479.0 ft Reverse circulated at 11491.0 ft Freeze protect well - 75.000 bbl of Diesel Freeze protect well - 65.000 bbl of Diesel Conducted slickline operations on Slickline eqmpment - Retrival run Conducted slickline operations on Slickline eqmpment - Setting run Conducted slickline operations on Slickline eqmpment - Retrival run Conducted slickline operations on Slickline eqmpment - Retrival run Conducted slickline operations on Slickline eqmpment - Setting run Conducted slickline operations on Slickline eqmpment - Setting run Conducted slickline operations on Slickline eqmpment - Setting run Conducted slickline operations on Slickline eqmpment - Retrival run Conducted slickline operations on Slickline eqmpment - Retrival run Conducted slickline operations on Slickline eqmpment - Setting run Flow check Rigged down Slickline unit Installed Hanger plug Removed Test choke manifold Removed Xmas tree Installed Xmas tree Tested Tubing bonnet Tested Xmas tree Removed Hanger plug Installed Hanger plug Removed Wellhead primary components Rigged down Additional services Badami Alaska State Plane Zone 3 Badami CPF B1-28 RECEIVED OCT 0 7 1998 BPXA PDC OR!G , 3. AL ..L SURVEY REPORT 24 September, '/998 Your Reft API-500292289900 Last Survey Date 19-September-98 Job# AKVCS0308 KBE - 55.62' spenn~/-sun DRILLING c; E RVI~- E c; Survey Ref: svy608 Badami Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 12138.75 36.190 46.580 8925.44 8981.06 12150.00 36.960 45.610 8934.47 8990.09 12191.84 29.270 40.560 8969.49 9025.11 12222.91 27.520 33.610 8996.83 9052.45 12254.21 27.610 25.480 9024.59 9080.21 12285.92 28.810 17.300 9052,54 9108.16 12317.31 30.860 9.380 9079.78 9135.40 12348.76 33.410 2.390 9106,42 9162.04 12380.34 35.390 357.490 9132.48 9188.10 12410.68 37.320 354.060 9156.92 9212.54 12442.37 39.550 350.700 9181.74 9237.36 12473.51 42.130 346.860 9205.30 9260.92 12505.72 43.410 341.650 9228.96 9284.58 12538.12 44.250 339.970 9252.33 9307.95 12632.92 44.600 340.650 9320.03 9375.65 12727.69 44.430 341.440 9387.61 9443.23 12821.71 43.890 341.380 9455.06 9510.68 12916.60 42.820 340.340 9524.06 9579.68 13010.67 40.360 338.620 9594.41 9650.03 13104.89 39.750 338.610 9666.53 9722.15 13199.82 37.830 337.730 9740.52 9796.14 13294.15 37.360 337.750 9815.26 9870.88 13388.86 36.900 338.010 9890.77 9946.39 13483.17 36.460 337.810 9966.40 10022.02 13577.91 35.980 337.320 10042.83 10098.45 13672.53 35.570 338.120 10119.60 10175.22 13767.05 35,430 338.540 10196.55 10252.17 13861,24 35.180 338,080 10273.42 10329.04 13956.11 34.610 338.670 10351.23 10406.85 14051.70 33,750 339.030 10430.31 10485,93 Sperry-Sun Drilling Services Survey Report for B'1-28 Your Ref: API-500292289900 Local Coordinates Northings (fi) 3939.41N 3944.06 N 3960.66 N 3972.41N 3984.98 N 3998.92 N 4014.09 N 4030.71N 4048.54 N 4066.46 N 4085.98 N 4105.94 N 4126.97 N 4148.16 N 4210.64N 4273.48 N 4335.56 N 4397.10 N 4455,58 N 4512.04N 4567.25 N 4620.51N 4673.47 N 4725.67 N 4777.41N 4828.60 N 4879.60 N 4930.18 N 4980.64N 5030,72 N Eastings 5651.05 E 5655.88 E 5671.55 E 5680.46 E 5687.59 E 5693.03 E 5696.59 E 5698.26 E 5698.23 E 5696.89 E 5694.26 E 5690.29 E 5684.34 E 5676,97 E 5654.61E 5633.03 E 5612.15 E 5590.79 E 5568.93 E 5546.82 E 5524.72 E 5502.92 E 5481.39 E 5460.21E 5438.84E 5417.87 E 5397.60 E 5377.48 E 5357.48 E 5338.10 E Global Coordinates Dogleg Vertical Northings Eastings Rate Section (fi) (fi) (°/100fi) (fi) 5910262.34 N 369746.48 E 6802.24 5910266.90 N 369751.40 E 8.658 6808,94 5910283.22 N 369767.36 E 19.513 6831.74 5910294.81 N 369776.48 E 12.028 6846.32 5910307.25 N 369783.83 E 12.015 6860.17 5910321.09 N 369789.52 E 12.758 6873.76 5910336.19 N 369793,35 E 14.137 6886.86 5910352.78 N 369795.33 E 14.324 6899.60 5910370.60 N 369795,61 E 10.773 6911.95 5910388.55 N 369794.59 E 9.238 6923.43 5910408.11 N 369792.32 E 9.639 6935.09 5910428.14 N 369788.70 E 11.559 6946.09 5910449.28 N 369783.14 E 11.678 6956.41 5910470.60 N 369776.14 E 4.429 6965.81 5910533.46 N 369754.91E 0.623 6993.09 5910596.68 N 369734.46 E 0.611 7021.18 5910659.13 N 369714,69 E 0.576 7049.25 5910721.04 N 369694.45 E 1.356 7076.60 5910779.91 N 369673.64 E 2.883 7101.47 5910836.75 N 369652.55 E 0.647 7124.75 5910892.35 N 369631.44 E 2.104 7147.16 5910945.99 N 369610.60 E 0.498 7168.45 5910999.33 N 369590.02 E 0,513 7189.72 5911051.90 N 369569.78 E 0.483 7210.71 5911104.02 N 369549.35 E 0.592 7231.25 5911155.57 N 369529.30 E 0.657 7251.69 5911206.93 N 369509.95 E 0.298 7272.51 5911257.87 N 369490.74 E 0.387 7293.15 5911308.67 N 369471.65 E 0.698 7313.77 5911359.09 N 369453.17 E 0.924 7334.59 Comment Tie-on Survey Window Point Alaska State Plane Zone 3 Badami CPF Continued... 24 September, 1998 - 16:02 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for B1-28 Your Ref: API-500292289900 Badami Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/t 00ft) (ft) 14146.46 33.050 339.340 10509.42 10565.04 14241.24 32.510 339.840 10589.11 10644.73 14310.00 32.510 339.840 10647.09 10702.71 5079.48 N 5319.57 E 5911408.18 N 369435,51E 0.760 7355,10 5127.57 N 5301.67 E 5911456.58 N 369418.48 E 0.637 7375.61 5162.26 N 5288.93 E 5911491.50 N 369406.37 E 0.000 7390.52 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 46.035° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14310.00ft., The Bottom Hole Displacement is 7390.65ft., in the Direction of 45.694° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 12138.75 8981.06 3939.41 N 5651.05 E Tie-on Survey 12150.00 8990.09 3944.06 N 5655.88 E Window Point 14310.00 10702.71 5162.26 N 5288.93 E Projected Survey Comment Projected Survey Alaska State Plane Zone 3 Badami CPF 24 September, 1998 - 16:02 - 3 - DrillQuest JUL, ' '998 10'i2AM NO. 3501 P, 2 ~' BP EXPLOR,~ION To: B.EWondzell P.E. Date: July I, 1998 State of Alaska Alaska Oil & Gas Conservation Commission From: Michael R. Cook Subject: Dis. pensafion for 20 AAC 25,03.5 (7){b) for Badami Development Shared Services Drilling/Badarni Development requests your consideration of a waiver of the diverter system identified in 20 AAC 25.035 (7)(b) "Secondary Well Control: Blowout Prevention Equipment (BOPE) Requirements" based upon exploration and development well drilling histories. Wells previously drilled through the Badami upper stratagraphic intervals have not experienced any difficulty with shallow gas prior to mnning and cementing of surface casing, typically at the 4500' tvdss depth. Please see attached detailed documents. Exploration well mud logging and siesmic survey data indicates an absence of any shallow gas hazard. Badami exploration well #1 and//4 did show some evidence of coal gas in the 2300' tvdss to 4200' tvdss interval. To date,wells; B1-01,B1-21,BI-II,BI-18,BI-14,BI-16 and Bl-15 have been drilled through the surface hole strata at Badami without encountering any shallow hydrocarbons or pressure. Additionally, Badami development wells B 1-14,B 1-16,B I- 15 have not utilized the Hydril 21-1/4" MSP diverter assembly per granted approval as noted on Permit to Drill form 10-401. The Bl-14 well was spudded April 4th, 1998 and the B 1-15 well is being drilled at present. M~!incerely' B adami Engineer TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 · PHONE: (907) 279-1433 FAX: (907) 276-7542 July 14. 1998 Mike e. Miller Badami Drilling Team Leader BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re~ Badami Unit B1-28 BP Exploration (Alaska) Inc. Permit No. 98-130 Sur. Loc.: 3858'NSL. 5266'WEL. Sec. 9. T9N. R20E. UM Btmhole Loc: 1794'SNL, 132'WEL. Sec. 4, T9N. R20E. UM Dear Mr. Miller: Enclosed is the approvcd application for permit to drill thc above referenced well. Thc permit to drill does not cxcmpt you from obtaining additional permits required by law from other governmental agcncies, and does not authorize conducting drilling operations until all other required permitting dctcrminations arc made. The rcqucst for a divcrtcr waiver is approved. Blowout prevention cquipmcnt (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximatcly 24 hours) of thc BOPE test performed before drilling below the surface casing shoe must be given so that a rcprcscntativc of thc Commission may witness the test. Notice may be given by contacting thc Commission pctrolcum ficld inspector on the North Slope pager at 659-3607 Chairman ~ BY ORDER OF TIlE COMMISSION dlt;'cnclosurcs cc; Department of Fish & Game. tlabitat Section w o encl. Department of Environmental Conservation w.o encl. ,. · STATE OF ALASKA ALASKA ~.;-L AND GAS CONSERVATION coMMISSION PERMIT TO DRILL / 20 AAC 25.005 DIVERTER WAIVER REQUESTED la. Type of work [] Drill [] Redrill lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []Service [] Development Gas F-ISingle Zone I--I Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 55.1' Badami !3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 365533/ 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3858' NSL, 5266' WEL, SEC. 9, T9N, R20E, UM Badami Unit At top of productive interval 8. Well Number Number 2S100302630-277 1875' SNL, 41' WEL, SEC. 4, T9N, R20E, UM B1-28 At total depth 9. Approximate spud date Amount $200,000.00 1794' SNL, 132' WEL, SEC. 4, T9N, R20E, UM 07/25/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVB) ADL 377011, 1794'I B1-21, 74' at 2575' MD 5120 14108' MD / 10680' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} KickOff Depth 12200' MD Maximum HoleAngle 42° Maximum surface 4400 psig, At total depth (TVD) 10094'/6326psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 37' 37' 116' 116' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC 5452' 35' 35' 5487' 4555' _~930 sx PF 'E', 360 Class 'G' 8-1/2" 7" 29# Pl10 BTC-Mod 11920' 33' 33' 11953' 8935' 185 sx Class 'G' 6" 4-1/2" 12.6# L~80 BTC 2208' 11900' 8892' 14108' 10680' LJncemented slotted liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented M D TVD Structural Conductor Surface Intermediate Production Perforation depth: measured true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Numbec Mike Miller, 564-5066 Prepared By Name/Number: Carol Withey, 564-4114 -. 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Mike E. Miller ~ ~ ~/~~--..~ Title Badami Drilling Team Leader Date Commission Use Only .erm,..um er i I Approva' Date I See cover,error ~ o°- l ~ 0 50- 0 Z e' - ,2 2. $ ~/~f 7 "" l'z/¢~' ~ ~ for other requirements Conditions of Approval: Samples Required []Yes [~No Mud Log Required []Yes [~]'No Hydrogen Sulfide Measures []Yes [] No Directional Survey Required ~Yes I-lNo Required Worki.ng Pressure for DOPE []2M; []3M; ,[~ 5M; [] 10M; [] 15M Other: I;;) ~ ~-~¢ Approved By d¢,g[fla! 5i6JRed By by order of ~_~..~,~ , . .., ,~h_-_otnn Commissioner the commission Date 1~'/ Form 10-401 Rev. 12-01-85 Submit In Triplicate B 1-28 Producer - Multi-lateral .. _J PERMIT B1-28 - HOLE #3- PRIMARY WELLBORE - Third penetration below 7" intermediate casing: I TD MD: I lTD TVDBRT: 1 0680 I Badami Sand A5 Primary 1875'FNL 41' FEL SEC 4, T9N, R20E, UM, AK target Bottom Hole Location (TD) 1794' FNL 132' FEL SEC 4, T9N, R20E, UM AK Formation Markers: Formation Tops MD TVD (bkb) Remarks Shallowest Badami Sand 12081 9035 Badami Sand J2 13387 10049 Badami Sand X3 13453 10105 Badami Sand F5 13747 10356 Primary Sand Badami Sand A5 13899 10492 Total Depth 14108 10680 Casing/Tub ing Program: Hole ~ize ' Cs'g/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/I'VD MD/TVD brt 6" 4-1/2" 12.6# L-80 BTC 2208 11900/8892 14108/10680 slotted liner (7" toTD) Tubing 4-1/2" 12.6# L-80 IBT 11767 33/33 11800/8814 Mod. Logging Program: Production Hole RFT Cased Hole Logs: MWD GR/Resistivity none none Directional: KOP: 112200'md/9118'tvd @ 40 deg Maximum Hole Angle: 42deg Close Approach Well: B1-01,B1-11,B1-18,B1-14 and B1-15 hole#1 and B1-15 hole#2 Shared Services Drilling Contact: B 1-28 Producer - Multi-lateral PERMIT Mike Miller 564-5066 I Well Name: I B1-28 I Well Plan Summary DATA COMMON TO ALL THREE PENETRATIONS (PRIMARY AND BOTH LATERALS): Type of Well (producer or injector): I Surface Location: IAFE Number: I Estimated Start Date: Producer- Multi-Lateral Open-Hole 3858' FSL 5266' FEL SEC 9, T9N, R20E, UM, AK I880459 I July 25, 1998 I KBE: 55.1 I · AMSL IRig Nabors 28E I I Operating days to complete: 148 I I Well Design: I Ultra slimhole- multi-lateral open hole completion w/slotted liner Formation Tops MD TVD (bkb) Remarks base permafrost 1959 1955 Top Middle Brookian (TMBK) 9380 7056 M90 10956 8181 Base West Sak (M85) 11340 8465 Casing/rub lng Pro~lram: Hole ,~ize T Csg~ Wt/Ft Grade Conn Length Top Btm Tb~l O.D. MD/rVD MD/rVD brt 24" 20" 91.1 Cf H-40 Weld 80 37/37 116/116 12-1/4" 9-5/8" 40Cf L-80 BTC 5452 35/35 5487/4555 8-1/2" 7" 29# P110 BTC- 11920 33/33 11953/8935 mod IInternal yield pressure of the 7" 29#/ft P110 casing is 11220 psi, which is greater than the maximum anticipated surface pressure of 4400 psi (6326 psi at 10094' tvd; gas, 0.1 psi/E, surfac~-~-~ 6570'; oil, 0.36 psi/ft, 6570 to 10094' tvd). Wellhead rating is 5000 psi for starting head (intermediate casing) and 10,000 psi for tubing head (10,000 psi is required not for drilling, but for injection, during which surface pressures will reach 5500 psi). BOPE is 10000 psi to match the wellhead rating and to allow for any remote chance that a higher pressure sand is encountered that would exceed 5000 psi shut-in surface pressures. Logging Program: IOpen Hole Logs' Surface Intermediate Production None MWD/GR @ hole section TD MWD/GR/RES · planned for entire hole section Mud Pro~lram: I Special desitin considerations B 1-28 Producer - Multi-lateral PERMIT displace OH laterals to 5% KCL water based muds Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 150 25 20 45 9 10 to to to to to to to 9.8 - 10.0 300 60 30 60 9.5 15 Intermediate Mud Properties: I KCL polymer Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.2 45 15 8 15 8.5 6-8 to to to to to to to 10.1 55 20 10 25 9.5 4-6 Production Mud Properties: I KCL polymer Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point ~lel gel Loss 12.0 45 10 8 15 8.5 4-5 to to to to to to to 12.4 55 15 10 20 9.5 4-5 Well Control (Secondary): Diverter Waiver Requested Well control equipment consisting of 10,000 psi W.P.(2) pipe rams, (1) blind rams, and 5M WP annular preventer will be installed and is capable of handling maximum potential surface pressures.lO M WP Choke & kill manifold. BOPE and drilling fluid system schematics on file. Waste Manaqement: Cuttings Handling: the cuttings will be processed through the onsite Grind and Inject facility and injected into disposal well B1-01. Surface gravels will be washed and stored for construction purposes. Fluid Handling: All drilling and completion fluids will be processed through the onsite Grind and Inject facility and injected into disposal well B1-01. Annular Injection: No annular injection is planned at this time. DRILLING HAZARDS AND RISKS: Wellbore proximity comments are addressed under each MLOH section. Junk (auger tooth) was encountered in the B1-16 conductor - if junk is encountered, ensure all junk is fished prior to commencing drilling. Stuck pipe - UGNU sands, West Sak Sands - differential Coals - stringers throughout well, 4500' to Canning formations at 9500' tvd. Badami sands are overpressured - normally 12.2ppg mw required at TD. Pressure transition begins just above shallowest sand. Shallow sands typically pressured between normal and the 12.2 ppg required in lower sands. Maintain minimum mud weight and utilize latest techniques to manage lost circulation hazards in shallow sands (flow rates, tapered drill string). Weight up as wellbore pressures dictate, maintaining a 200 psi overbalance throughout. B 1-28 Producer - Multi-lateral ,~ l, · :. PERMIT Hazards of well control and stuck pipe are managed by setting 7" casing above shallowest sand, before penetrating the full overpressure. Hazard of lost circulation is managed by proper techniques to maintain Iow ECD - ECD of 13.5 ppg noted to be maximum allowable to prevent lost circulation. B 1-28 Producer - Multi-lateral PERMIT Badami B1-28 Multi-lateral Proposed Summary of Operations 1. Weld the starting head on the conductor. 2. Prepare the location for the rig move. 3. MIRU Nabors 28E drilling rig. Build spud mud. A diverter is requested from AoGCc. 4. PU 12-1/4" bha & drill surface hole as per directional plan. Run directional MWD from surface to TD. .~. 5. Run 9-5/8" surface casing and cement to surface in two stages. 6. NU 13-5/8" 10M BOPE. Test BOPE to 5000 psi. 7. RIH with BHA, test casing to 3000 psi. Drill out float equipment and 20' of new formation. Perform a LOT as per SSD Standard Operating Procedure. Contact the Badami Drilling Team Leader or SSD Superintendent with LOT test results before drilling ahead. 8. Drill 8-1/2" hole to intermediate casing TD as per directional plan, with MWD directional surveys. 9. Run 7" casing and cement as per Cement Procedure (1000' md of cement above shoe). Test BOPE to 6000 psi. 10. Drill out float equipment and 20' of new formation. Perform FIT to 13.5 ppg minimum equivalent. 11. Drill 6" hole to B1-28 L1 - [Hole #1] target TD as per directional plan with GR/Resistivity MWD. Utilize latest techniques for reducing lost circulation risk (tapered string, flow rate limitations, ECD limits, mud rheology, etc.). 12. If insufficient interval of amalgamated pay exists as determined by logs, no slotted liner will be run in this hole. If a sufficient interval of amalgamated pay exists as determined by logs and petrophysicist, run 4-1/2" slotted liner (with inner string) from TD to just above the top of the amalgamated pay (exact depths to be determined from logs). [This will leave open hole above top of slotted liner]. Set liner on bottom, release from liner with HES hydraulic setting tool. Displace liner and open hole to above KOP for B 1-28 L2 [Target #2] to kill-weight water based mud w/5% KCL. POOH. 13. RIH with BHA and perform open-hole, low-side kickoff. Use most aggressive BHA design to ~et off (tricone or PDC sidetrack bit, 1.83 - 2.15 motor housing bend, etc.) Drill to B 1-28 L2 [Hole #2] target TD as per directional plan with GR/Resistivity MWD. 14. If insufficient interval of amalgamated pay exists as determined by logs, no slotted liner will be run in this hole. If a sufficient interval of amalgamated pay exists as determined by logs and petrophysicist, run 4-1/2" slotted liner (with inner string) from TD to just above the top of the amalgamated pay (exact depths to be determined from logs). Set liner on bottom, release from liner via hydraulic releasing tool. Displace liner and open hole to above KOP for B 1-28 [Target #3] to kill-weight water based mud with 5% KCL. POOH. 15. RIH with BHA and perform open-hole, low-side kickoff. Drill to B1-28 [Hole #3] target TD as per directional plan with GR/Resistivity MWD. This will be designated the primary wellbore. 16. Run 4-1/2" slotted liner (with inner string) from TD to above top of shallowest sand, and blank 4- 1/2" liner from above top of shallowest sand to 50' inside the 7" intermediate casing. Release from liner via hydraulic releasing tool. Displace liner and open hole to above KOP for B 1-28 [Target #3] to kill-weight water based mud with 5% KCL. POOH. B 1-28 Producer - Multi-lateral PERMIT 17. RIH with 4-I/2" completion assembly with 3.813" PXN plug in place in "XN" nipple. Fill tubing with 8.6# fresh water while running in hole. Position Halliburton "TNT" packer setting depth to +/- 100' md above 7" 29# intermediate csg. shoe. Record pick up and slack off weights. 18. M/U connect 2 ea. ~,4" 316 SS 0.049" wt. WLRSV landing nipple control lines to FMC 4-1/16" 10 M tubing hanger. Test control lines to 5000 psi - hold pressure for 10 mins. 19. Land FMC 4-1/16" 10 M tubing hanger and RILDS to energize FMC tubing hanger packoff assembly. 20. Pressure up tubing to 500 psi. Shut down and monitor pressure for leaks. Pressure tubing to 7000 psi to set production packer. Reduce pressure to 3500 psi. Hold pressure for 30 minutes and record 6n Barton recorder chart as 4-1/2" tubing pressure test. Maintain 4-1/2" tubing pressure at 3500 psi and pressure up 4-1/2" x 7" annulus to 3500 psi.. Hold pressure for 30 minutes and record on Barton recorder chart as 4-1/2 "x 7" annular pressure test. Bleed 4-1/2"x7" annulus pressure off prior to bleeding down tubing pressure. Notify the AOGCC 24 hours prior to testing the tubing and the annulus for AOGCC witnessing. Complete the AOGCC MIT test forms. Fax form to AOGCC and ENS/Badami offices. 21. Back out and L/D landing joint. Install "two way" check valve in FMC 4-1/16" 10M hanger profile. 22. Nipple down 13-5/8" 10 M Hydril BOPs. Nipple up the FMC 11" 10M x 4-1/16" 5M tubing head adapter and Cameron 4-1/16" 5M tree. Test control line to 5000 psi. Test the tubing head adapter and Cameron 4-1/16" 5M tree to 5000 psi. Pull the "two way" check valve. Orient tree wing valve and S-riser/downcomber as per Badami orientation diagram. 23. Pressure up on 4-1/2" x 7" tbg/csg, annulus - shear RP valve in lower GLM station. RP shear valve requires 2900 psi of differential pressure to shear. Calculated surface annular pressure to shear "open" the RP shear valve is +/- 1200 psi. 24. Pump down 4-1/2" 12.6# IBT L80 tubing to displace mud from the 4-1/2"x 7" annulus. Maximum displacement rate = 3 bpm through RP valve. Freeze protect well with diesel by "U" tubing from annulus side to tubing side. 25. R/U slickline. Pull WLRSV dummy. 26. RIH w/slickline and retrieve RP valve in lower GLM, pooh., RIH w/ slickline w/dummy valve, and locate in lower GLM sidepocket. 27. RIH w/ slickline and pull pressure equalizing prong in "PXN" plug. Pull "PXN" plug'body. Caution' Be aware of differential pressure below "PXN" plug during pulling operations - adjust for downhole differential pressure with equal surface pressure. 28. RIH w/ WLRSV and locate in HXO landing nipple. 29. Close SSSV & install two-way check, Secure well. RD/MO Nabors 28E rig, release rig. Transfer custody of well to Operations. B 1-28 Producer - Multi-lateral PERMIT Badami B1-28 CASING SIZE: 9-5/8" SPACER: SURFACE CASING CEMENT PROGRAM - HALLIBURTON 100 bbls fresh water. STAGE1 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: STAGE1 TAIL: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk 430 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on gauge hole annular capacity from 1000' above the casing shoe to the ES cementer at 2200' md, plus 30% excess. Premium 2% calcium chloride 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk 360SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on 1000' md of fill in the gauge hole plus 30% excess plus 80' shoe joint. SPACER: 50 BBLS FRESH WATER STAGE 2: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk 2500 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ' Volume based on gauge hole annular capacity from the ES Cementer at 2200' surface plus 250% excess, plus casing capacity from surface to the stage collar. Note: Pump until cement returns are observed at surface. WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY WITH APPROVAL OF APPROPRIATE SUPERINTENDENT IF THERE ARE NO CEMENT RETURNS TO SURFACE OR THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX NO SACKS: To be determined on job x job basis B 1-28 Producer - Multi-lateral PERMIT INTERMEDIATE CASING CEMENT PROGRAM- HALLIBURTON CASING SIZE: 7" SPACER: 20 bbls fresh water preflush followed by 50 bbls alpha spacer weighted 1ppg above current mud weight. CEMENT: ADDITIVES: WEIGHT: APPROX #SACKS: Premium HR-5 as required (retarder), .2% Halad-344 (fluid loss), 0.2% CFR-3 (dispersant) 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk 185 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on 1000' md of gauge hole annular capacity from shoe, plus 50% excess, plus 80' shoe joint. MULTI-LATERAL WELL ABANDONMENT PROGRAM The following program is to be used at such time as the wellbores below the 7" intermediate casing are to be abandoned. 1. MIRU Rig. 2. Kill Well. 3. Pull tubing, packer, completion. 4. RIH with 7" EZSV cement retainer and set 50-100' inside the 7" intermediate casing and above all perforations in the 7", if any exist. 5. Mix and pump a volume of premium class G cement to fill the 7" casing below the EZSV and the calculated volume to fill the entire hole section of all wellbores below the 7" shoe, plus 10%. 6. Unsting from EZSV. 7. Pressure test the EZSV and cement to 3000 psi. 8. Procedures for the remainder of the wellbore above the EZSV will depend on the future plans for the wellbore (total abandonment, sidetrack, etc.). 10 JUN-22-98 NON 11:07 ~H SPERRY-SUN ~L~$K~ .{ NO, 19075635754 5631 SIIverado Way #G · Anchorage, Alaska 99518 (907) 563-3256 Fax (907) 563-7252 P, 02 Shared Services Ddlling Mike Cook Approved Well Close Approach Review Badami / B1-28 Wp4 Mike, The above mentioned well has b~en rearmed usln~ ttaadard anti-collblon tmthod~ via DF. AP. Th~ scan wu p~ff~mt, d with the follow/m; p~ramete~: Start .<;,~n In~peeOoa ~ 35.30' End ~ [n~eeU~n Zone 14f329A2 Starting Scan Radius 200.00 Rate of Radius ]ncvease (p,.t 10~') 100,00 ' AniI-Collldon .Scan summary: Al~e plan~edKOPtbeStanJngSonRadha J~ 9&235' largt, rthtnDEAFJ dmfault~el:Ln~oi 100'$iartScanRaRh.~increa.~lng aLS0' ' prr LO00 'MD for, t~w-arill well scan, thus DEAP't dis~a~t~ win.lid be equal to 101.765' at the St~. ~ ~ ~n~ u stated above. 'l'hes~ numbers are used to prodt~ a t"mal s~an radius of 1~29,412' which It 812,941' In~ than DEAFs default value of 816.471' Scan Parameters Comments: At (his cnla~ged radius the following welb wet~ detec~od during th~ scan (Baaed on closest'Allows'He DevOtion &-om Plan3: Note: thL~ Iht may not iuclude all the, weib detected, on]y Ihose, of which ~ro of coao~m ot n~y effect Tole, r~c~ Linc cLrawingl Comuarlson Suble~A Wdl ~ Relative ~ ~ Del)th ' ~(~erntion ~ D~s0on BI-0i 799.52'MD 271.43 ' 267.20 · 264.69 ' BI.11 1598.59"N{D ~'L., 183.31 ' 251.90 · 172A4 ' BI-14 2596.21 7vid 303.89 ' 325.60 · 288,10 ' BI.16 2386.95'lviT) 137.33 ' 304.20 · 12333 ' BI.16 Pbl 2386.94 'M/) 137.31 ' 304.20 · 123,30 ' B1-18 2396.50 'MD 114.17 ' 263.00 ' 98.10 ' B1-2I 2375.05 'M]3 89,93 ' ~.3.50 ° 73.7'/ ' Dndam{-01 4401.21 'MD 367,56 ' 169.50 ° 297.52 ' No No No No No No No No Minor Minor Minor Minor Minor Minor Minor Minor Tolernnce Plot required: Ye~ Close Approach Comments: Close Approach Scan Performed bye. ~. 66,- / Date: Checked by: ,~,..~.~. Approved by: FOR PERMITTING ONLY Datc: BI-21 Wp4 _ AWD Proximity Review -j <:: ;.: , ? .: -;. BP EXPLORATION, Alaska Date: 01-26-99 Trans~ 90195 BADAMI LOG DATA Enclosed are the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 Sw Rec Rec Date Company Comments Name Type Code B1-28 OH 20-Sep-98 SPERRY MWD, MD, ROP, NGP, DGR, EWR4- OTHER SERVICES DIR. DRILLING, MUDLOGGING B1-28 OH 20-Sep-98 SPERRY MWD, TVD, NGP, DGR, EWR4- OTHER SERV DIR DRILLING, MUDLOGGING B1-28L1 DISK 25-Aug-98 SPERRY MWD, MPT, GR, EWR4, ROP Please sign and return one copy of this Carla H. Mclntosh Petrotechnical Data Center LOG DATA AOGCC-1 blueline/1 sepia/1 disk Howard Oakland PETROFINA-1 blueline/1 sepia/1 disk Mike Engle DNR - 1 bluelinell disk Tim Ryherd BP - - 1 blueline Dave Goodwin MB 7-2 BP- - 1 blueline Ken Lemley (distributed by Dave Goodwin) RECEIVED Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION, Alaska Date: 01-20-99 Tran~ 90170 BADAMI LOG DATA AND DISKS Enclosed are the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 Sw Name Rec Type Rec Date Company Code Comments B1-28 DISK 19-Sep-98 SPERRY MWD, MPT, GR, EWR4, ROP B1-28L1 OH 26-Augo98 SPERRY MWD, MD, ROP, NGP, DGR, EWR4 B1-28L1 OH 26-Aug-98 SPERRY iMWD, TVD, NGP, DGR, EWR4 B1-28L2 OH 09-Sep-98 SPERRY IMWD, MD, ROP, NGP, DGR, EWR4 B1-28L2 OH 09-Sep-98 SPERRY MWD, TVD, NGP, DGR, EWR4 B1-28L2 DISK 08-Sep-981 SPERRY MWD, MPT, GR, EWR4, ROP Please sign and return one copy of this tra~- Carla H. Mclntosh LOGPetrotechnical Data Center DATA AOGCC-1 blueline/1 sepiaJl disk Howard Oakland PETROFINA-1 blueline/1 sepia/1 disk Mike Engle DNR - 1 blueline/1 disk Tim Ryherd BP - - 1 blueline Dave GOodwin MB 7-2 BP--1 correlation blueline Ken Lemley RECEIVED JAN 21 1999 Alas~30il & Gas Cons. 6o~ Andlomge Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 JUN-22-98 NON 11:09 SPERRY-SUN ~L~SK~ FAX NO, 1907R835754 P, 09 Badami Alaska State Plane Zone 3 Badami CPF B1-28 Wp4 L2 PROPOSAL REPORT 20 May, 1998 Your Reft B1-28 MLOH (Hole#3) Surface Coordinates: 5906425.00 N, 364025.63 E (70° 09' 08.0405" N, 147° 05' 36.3229" W) D R IL-.. L I N I~ Proposal Ref: pro234 JUN-22-98 NON 11:10 ~M SPERRY-SUN ~LaSK~ NO, 18076635754 P, l0 · ~. ,... S~ale= linch = 600fl Eastings 4500 51~ 57~ 6300 6900 ,I . , I. . I I I . I 6o~ - ~ - 6~ ~ Total Depth: 14107.9~ MD, I0~0.10fl WD I~32.88 ~D -4828.3 ~, 5210.~ E ~ i I II II ~?~ Tande~ a 13M"11~: ,~,8.4~l MD, 9438.28fl TVD 4600 5100 5700 6300 6900 Scale: linch = 600ff Eastings Reference la True Nodh ~oo.~ 7" Casing · 11953.35 MD, 8935.10 ~D 1~4~ ~~BHA Tendency ~ 1.~4=/1~: 12618.40fl MD, g438.28ff~D 10200 -; ~3~oo.~ , 6600 ~ 7200 78~ 8~ Scale: linch ~ 600ff S~l~n Azlm~h: 4~,202' ~me PROPOSALTAReEfSUMMA~Y , SURFACE LocATiON'- Name: TVDfiS WORKB: Wel~d Offsela: G~ ~les: R~ ~al~: 35.~ fl R~ (~ ' ' __ Hole~3 10377.78 10432.88 4828.31 N, 52~0.~ E 59~1159.~ N, 36~22.10 E I (~Radlus) I ............................. Sperry-Sun Drilling Services Proposal Data - B1-28 - B1-28 Wp4 L2 FOP. PERMITTING ONLY z CD DriliQuest Badami Measured Depth (ft) 12200.00 12300.00 124O0.00 12500.00 12600.00 12618.40 127OO.O0 12800.00 12900.00 13000.00 13100.00 13200.00 13300.00 13387.61 13400.00 13453.96 13500.00 13600.O0 13700,00 13791.79 13800.00 13832.36 13899.12 13900.00 14OO0.00 14100.00 14107.99 Incl. 48.909 40.276 37.387 37.679 41.084 42.000 40.997 39.775 38.562 37.359 36.167 34.987 33.821 32.811 32.669 32.055 31.534 30.418 29,322 28.337 28.25o 27.9o8 27.088 27.077 25.861 24.662 24.567 Azim. Sub-Sea Depth (ft) Vertical Depth (ft) Sperry-Sun Drilling Services Local Coordinates Northings Eastings (ft) (ft) Proposal Report for B1-28 Wp4 L2 Your Ref: B1-28 MLOH (Hole#3) FOR PERMITTING ONLY Alaska State Plane Zone 3 Badami CPF 41.546 9062.84 9117.94 4031.10 N 5583.48 E 29.616 9134.11 9189.21 4087.61 N 5624.60 E 10.980" 9212.27 9267.37 4145.72 N 5646.43 E 351.227 9291.86 9346.96 4205.95 N 5647.56 E 333.031 9369.41 9424.51 4265.66 N 5627.92 E 330.000 9383.18 9438.28 4276.38 N 5622.10 E 329.217 9~,~4.30 9499.40 4323.02 N 5594.75 E 328.214 9520.47 9575.57 4378.39 N 5561.12 E 327.157 9598.00 9653.10 4431.77 N 5527.36 E 326.044 9676.84 9731.94 4483.13 N 5493.51 E 324.868 9756.95 9812,05 4532.43 N 5459.58 E 323.623 9838,28 9893.38 4579.64 N 5425.59 E 322.303 9920,79 9975.89 4624.75 N 5391.57 E 321.080 9994.00 10049.10 4662.51 N 5361.75 E 320.901 10004.42 10059.52 4667.72 N 5357.53 E 320.108 10050.00 10105.10 4690.00 N 5339.17 E 319.409 10089.14 10144.24 4708.52 N 5323.49 E 317.819 10174.87 10229.97 4747.14 N 5289.48 E 316.120 10261.59 10316.69 4783.55 N 5255.51 E 314.456 10342.00 10397.10 4815.01 N 5224.38 E 314.302 103492.3 10404.33 4817.73 N 5221.60 E 313.687 10377,78 10432.88 4828.31 N 5210.64 E 312.765 10437.00 10492.10 4849.42 N 5188.18 E 312.752 10437.79 10492.89 4849.70 N 5187.89 E 311.268 10527.30 10582.40 4879,53 N 5154.78 E 309.650 10617.74 10672.84 4907.23 N 5122.32 E 309.514 10625.00 10680.10 4909.35 N 5119.76 E Global Coordinates Dogleg Vertical Northings Eastings Rate Section (fi) (ft) (°/1O0ff) Comment 5910355.23 N 369680.57 E 6820,06 5910410.99 N 369722.69 E 12.000 6888.85 5910468.71 N 369745.57 E 12.000 6944.84 5910528.90 N 369747.77 E 12.000 6987,33 5910588.95 N 369729.21 E 12.000 7014.49 5910599.78 N 369723.59 E 12.000 7017.71 5910646.90 N 369697.08 E 1.384 .7030.24 5910702.87 N 369664.44 E 1.384 7044.29 5910756.85 N 369631.65 E 1.384 7056.87 5910808.80 N 369598.72 E 1.384 7067.98 5910858.70 N 369565.69 E 1.384 7077.61 5910906.52 N 369532.55 E 1.384 7085.76 5910952.23 N 369499.35 E 1.384 7092.42 5910990.52 N 369470.21 E 1.384 7097.03 5910995.80 N 369466.08 E 1.384 7097.59 5911018.41 N 369448.12 E 1.384 7099.76 5911037.21 N 369432.78 E 1.384 7101.27 5911076.43 N 369399.47 E 1.384 7103.44 5911113.45 N 369366.15 E 1.384 7104.12 5911145.46 N 369335.59 E 1.384 7103.43 5911148,23 N 369332.86 E 1.384 7103.30 5911159.00 N 369322.10 E 1.384 7102.72 5911180.52 N 369300.02 E 1.384 7101.12 5911180.79 N 369299.73 E 1.384 7101.10 5911211.22 N 369267.17 E 1.384 7097.85 5911239.50 N 369235.21 E 1.384 7093.60 5911241.66 N 369232.68 E 1.384 7093.21 Tie-on, Start Dir @ 12.000°/100ft- 12200.00ft MC), 9117.94ff TVD BHA Tendency @ 1.384°/100ft · 12618.40ff MD, 9438.28ff TVD F3 F5 ' Target: B1-28 Hole#3, 200.00 Radius., Geological A5 Total Depth ' 14107.99ft MD, 10680.1 Oft 'I'VD 4 1/2" Liner Z ContJ'nued... 20 May, 1998 - 12:07 .1 - Dri/IOuest Sperry-Sun Drilling Services Proposal Report for B 1-28 Wp4 L2 Your Ref: B1-28 MLOH (Hole~3) Badami FOR P£RMITTING ONLY All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. The Dogleg Sevedty is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 46.202° (True)_ Based upon Minimum Curvature type calculations, at a Measured Depth of 14107.99ft., The Bottom Hole Displacement is 7093.21ff., in the Direction of 46.202° (True). Alaska State Plane Zone 3 Badami CPF 0 z x z o DrillOuest 20 May, 1998 - 12:07 -2- JUN-22-98 PION I1:11 ~,H SPERRY-SUN ~LASKA FAX NO, 19075635754 P, 14 Badami Sperry-Sun Drilling Services Proposal Report for B1-28 Wp4 L2 Your Ref: B1-28 MLOH (Hole#3) FOR PERMITTING ONLY Alaska State Plane Zone 3 Badami CPF Measured Vertical Closure Depth Incl. Azim. Depth Northings Eastings Distance Direct'n (ft) (ft) (ft) (ft) (ft) Vertical Dogleg Section Rate (fi) (°/100ft) 12200.00 48,909 41.546 9117,94 4031,10 N 5583.48 E 6886,58 54.172 12300.00 40.276 29.616 9189,21 4087.61 N 5624.60 E 6953.03 53.993 12400.00 37.387 10.980 9267.37 4145,72 N 5646.43 E 7004.94 53.713 12500,00 37.679 351.227 9346.96 4205,95 N 5647.56 E 7041,66 53.324 12600,00 41,084 333.031 9424,51 4265.66 N 5627,92 E 7061.83 52.840 12618,40 42,000 330.000 9438.28 4276.38 N 5622,10 E 7063.67 52.742 12700.00 40,997 329,217 9499.40 4323.02 N 5594.75 E 7070.35 52,307 12800,00 39.775 328.214 9575,57 4378.39 N 5561.12 E 7077.88 51.786 12900.00 38.562 327.157 9653.10 4431,77 N 5527.36 E 7084.65 51.278 13000.00 37,359 326,044 9731,94 4483.13 N 5493,51 E 7090.63 50.783 13100.00 36.167 324.868 9812.05 4532.43 N 5459.58 E 7095.77 50,301 13200,00 34.987 323,623 9893.38 4579.64 N 5425.59 E 7100.02 49.833 13300.00 33,821 322,303 9975,89 4624.75 N 5391,57 E 7103.33 49.378 13400,00 32.669 320,901 10059.52 4667.72 N 5357.53 E 7105,68 48.936 13500,00 31,534 319,409 10144.24 4708.52 N 5323,49 E 7107,02 48..~08 13600.00 30.418 317,819 10229,97 4747.14 N 5289.48 E 7107.32 48.093 13700,00 29,322 316,120 10316,69 4783.55 N 5255.51 E 7106,53 47.692 13800.00 28.250 314.302 10404.33 4817.73 N 5221.60 E 7104.62 47.304 13832,36 27,908 313.687 10432,88 4828.31 N 5210.64 E 7103.76 47.181 13900.00 27.077 312,752 10492,89 4849.70 N 5187.89 E 7101,67 46.930 14000,00 25.861 311,268 10582.40 4879.53 N 5154.78 E 7098.00 46.571 14100.00 24.662 309.650 10672,84 4907,23 N 5122.32 E 7093.60 46.229 14107.99 24,567 309.514 10680.10 4909,35 N 5119.76 E 7093.21 46.202 6820.06 6888.85 12.000 6944.84 12,000 6987.33 12.000 7014.49 12,000 7017.71 12,000 7030.24 1.384 7044.29 1.384 7056,87 1,384 7067.98 1.384 7077.61 1.384 7085,76 1.384 7092.42 1.384 7097.59 1.384 7101.~7 1.384 7t03.44 1.384 7104.12 1.384 7103.30 1.384 7102.72 1.384 7101,10 1,384 7097.85 1.384 7093.60 1.384 7093,21 1.384 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference, Northings and Eastings are relative to Well Reference. The Dogleg Severity is in Degrees per 100ff. Vedical Section is from Well Reference and calculated along an Azimuth of 46.202° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14107.99ft., The Bottom Hole Displacement is 7093.21ft,, in the Direction of 46.202° (True). 20 May. 1998 o 12:07 .2 - DrtllQuest VENDOR DATE INVOICE ! CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 04-22c28 CKO4229.8. D _i. 00. O0 i' L:,U. ~ "' O~'i.,_ HANDLINg INST' S/H ~{ATHY CAMPOA~OR X 5122 · WELL PERMIT CHECKLIST COMPANY _~ V¢ WELL NAME [~a~,~ _~ '~-~? PROGRAM: exp [] dev J2i~, redrll [] serv [] wellbore seg II ann. disposal para req fl FIELD&POOL b ("~ 0 l(~ 0 INIT CLASS D E tJ ! - 0 CL.- GEOL AREA L.~ ~ 0 UNIT# 1 0 ~ L~ ~ ON/OFF SHORE ADMINISTRATION ENGINEERING APPR. DATE 1. Permit fee attached ....................... 2. Lease number appropriate ................... (~ N 3. Unique well name and number .................. (~ N 4. Well located in a defined pool .................. N 5. Well located proper distance from drilling unit boundary .... N 6. Well located proper distance from other wells .......... N 7. Sufficient acreage available in drilling unit ............ (~ N 8. If deviated, is wellbore plat included ............... '~d N 9. Operator only affected party ................... ~ N 10. Operator has appropriate bond in force ............. (~_ N 11. Permit can be issued without conservation order ........ .~(~ N 12. Permit can be issued without administrative approval ...... (.~ N 13. Can permit be approved before 15~day wait ........... ~ N GEOLOGY AI~R DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved. 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to .~z"Oo(~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29 Is presence of H2S gas probable ................. N N N N N 30. Permit can be issued w/o hydrogen sulfide measures.. ~ Y N 31. Data presented on potential overpressure zones_..~~.. Y N 32. Seismic analysis of shallow gas zones.~.~., ........ Y N 33. Seabed condition sur~ ............. Y N 34. C~eekly progress reports ....... Y N ory onlyJ With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N ANNULAR DISPOSAL 35. APPR DATE GEOLCG~Y: ENGINEERING: UIC/Annular R_B_C__[:t'-~ BEW ~ ~ WM /¢,,~'~.~.. JDH COMMISSION: DWJ~ R N C._,..~_~.~_~f~ co _C_~o 'rl~,~ Comments/Instructions: M:cheklist rev 05/29/98 dlf: C :\msofficc\wordiar]\dia r~a\ct'~er;kli,~;t Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Fri Jan 15 16:20:48 1999 Reel Header Service name ............. LISTPE Date ..................... 99/01/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 99/01/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER BADAMI MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: B1-28 500292289900 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 15-JAN-99 MWD RUN 5 MWD RUN 6 MWD RUN 7 AK-VC-80308 AK-VC-80308 AK-VC- 80308 J. PANTER M. CADY M. CA/DY B. OWENS B. OWENS D. MASKELL RECEIVED JAN 2.1 1999 Alaska Oit&Gas Cons. JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: R3LNGE: FNL: FSL: MWD RUN 8 AK-VC-80308 M. CADY J. BOYD MWD RUN 16 AK-VC- 80308 K. ALLEN D. MASKELL 9 09N 20E 3858 FEL: 5266 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: 55.60 DERRICK FLOOR: 54.10 GROUND LEVEL: 19.60 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 20.000 116.0 2ND STRING 12.250 9.625 5445.0 3RD STRING 8.500 7.000 12035.0 PRODUCTION STRING 6.000 14310.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1,2,3,4,11,12,14, AND 15 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 3. MWD RUNS 9,10 AND 13 CONTAIN NO VALID DATA AND ARE NOT PRESENTED. 4. MWD RUNS 5 AND 6 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP). 5. MWD RUNS 7,8 AND 16 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 6. A CHANGE FROM SCINTILLATION TYPE GAMMA RAY (NGP) TO DUAL GAMMA RAY (DGR) OCCURRED AT 11987'MD, 8855'TVD. 7. ALL MWD DATA FROM 12150'MD, 8990'TVD TO 12556'MD, 9321'TVD IS MEASURED AFTER DRILLING (MAD) WHILE TRIPPING IN FOR MWD RUN 16. 8. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM DAVE GOODWIN OF BP EXPLORATION (ALASKA), INC. ON 03 NOVEMBER, 1998. 9. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14310'MD, 10702'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NIIMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 5400.0 14262.0 ROP 5461.5 14309.5 FET 12050.0 14269.0 RPD 12050.0 14269.0 RPM 12050.0 14269.0 RPS 12050.0 14269.0 RPX 12050.0 14269.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 5 5461.0 9996.0 6 9996.0 12056.0 7 12056.0 12130.0 8 12130.0 12150.0 16 12150.0 14310.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD RPS MWD RPM MWD RPD MWD FET MWD OHMM OHMM OHMM OHMM HOUR 1 68 1 68 1 68 1 68 1 68 12 16 2O 24 28 Name Min DEPT 5400 ROP 2.68 GR 20 RPX 1.3467 RPS 2.0902 RPM 2.2813 RPD 2.8568 FET 1.311 Max 14309.5 1814.06 156 231 295 956 150 524 128 001 194 115 111 951 Mean Nsam 9854.75 17820 137.03 17697 88.9152 17639 9.76612 4439 9.24922 4439 8.5965 4439 9.50107 4439 11.1273 4436 First Reading 5400 5461.5 5400 12050 12050 12050 12050 12050 Last Reading 14309.5 14309.5 14262 14269 14269 14269 14269 14269 First Reading For Entire File .......... 5400 Last Reading For Entire File ........... 14309.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE AUJMBER: 2 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 GR 5400.0 9927.5 ROP 5461.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM A=NGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP $ 9996.0 NATURAL GAMMA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN il-AUG-98 ISC 5.06 PCD 3.01E MEMORY 9996.0 5461.0 9996.0 46.7 57.2 TOOL NUMBER NGP SPC 217 8.500 8.5 GEL/WATER 9.90 63.0 8.2 600 5.3 .000 .000 .000 .000 116.4 .6 Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 5 FT/H 4 1 68 4 2 GR MWD 5 API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 5400 9996 7698 9193 5400 ROP 4.5783 1814.06 180.792 9070 5461.5 GR 20 151.923 81.9343 8970 5400 Last Reading 9996 9996 9927.5 First Reading For Entire File .......... 5400 Last Reading For Entire File ........... 9996 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 R_AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9928.5 11987.0 ROP 9997.5 12055.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MLTD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined 13-AUG-98 ISC 5.06 PCD 3.01E MEMORY 12056.0 9996.0 12056.0 33.8 50.0 TOOL NUMBER NGP SPC 183 8.500 8.5 GEL/WATER 9.90 58.0 8.2 600 4.9 .000 .000 .000 .000 133.3 .6 Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 6 FT/H 4 1 68 4 2 GR MWD 6 API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9928.5 12055.5 10992 4255 9928.5 ROP 10.2344 1019.53 129.35 4117 9997.5 GR 36.9231 156.231 99.0683 4118 9928.5 Last Reading 12055.5 12055.5 11987 First Reading For Entire File .......... 9928.5 Last Reading For Entire File ........... 12055.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/15 Maximum Physical Recordo.65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/15 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: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11988.5 ROP 12030.0 FET 12050.0 STOP DEPTH 12088.5 12129.5 12095.5 RPD 12050.0 RPM 12050.0 RPS 12050.0 RPX 12050.0 $ 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: MAXIMI/M ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 $ 12095.5 12095.5 12095.5 12095.5 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MLrD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 18-AUG-98 ISC 5.06 PCD 3.01E MEMORY 12130.0 12056.0 12130.0 .0 .0 TOOL NUMBER P0997GR4 P0997GR4 6.000 6.0 KCL POLYMER 10.20 68.0 9.7 22500 11.1 .190 .000 .140 .350 112.0 .0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 DEPT ROP GR RPX RPS RPM RPD FET Name Service Order Units Size Nsam Rep FT 4 1 68 MWD 7 FT/H 4 1 68 MWD 7 API 4 1 68 MWD 7 OHMM 4 1 68 MWD 7 OHMM 4 1 68 MWD 7 OHMM 4 1 68 MWD 7 OHMM 4 1 68 MWD 7 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Min 11988.5 7 4723 53 6454 1 3467 2 0902 2 2813 2 8568 2 7032 Max Mean Nsam 12129.5 12059 283 430.797 74.4061 200 125.145 84.9735 201 8.7523 5.28413 92 8.5429 5.69463 92 8.8006 5.56074 92 8.8863 5.78592 92 111.951 17.7721 92 First Reading 11988.5 12030 11988.5 12050 12050 12050 12050 12050 Last Reading 12129.5 12129.5 12088.5 12095.5 12095.5 12095.5 12095.5 12095.5 First Reading For Entire File .......... 11988.5 Last Reading For Entire File ........... 12129.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/15 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 ....... 99/01/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 R3tW MWD Curves and lo9 header data for each bit run in separate files. BIT RUN NI3MBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12089.0 12150.0 FET 12095.0 12150.0 RPD 12095.0 12150.0 RPM 12095.0 12150.0 RPS 12095.0 12150.0 RPX 12095.0 12150.0 ROP 12130.0 12150.0 $ 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 18-AUG-98 ISC 5.06 PCD 3.01E MEMORY 12150.0 12130.0 12150.0 33.4 48.2 TOOL NUMBER P0997GR4 P0997GR4 6.000 6.0 KCL POLYMER 11.20 49.0 8.3 18500 9.0 .190 .110 .140 .350 125.0 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 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .0 Name Service Order Units Size Nsam DEPT FT 4 1 ROP MWD 8 FT/H 4 1 GR MWD 8 API 4 1 RPX MWD 8 OHMM 4 1 RPS MWD 8 OHMM 4 1 RPM MWD 8 OHMM 4 1 RPD MWD 8 OHMM 4 1 FET MWD 8 HOUR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name Min Max Mean DEPT 12089 12150 12119.5 ROP 9.7484 122.812 40.1848 GR 79.4923 117.907 93.072 RPX 6.1296 8.9281 7.626 RPS 6.773 9.6702 8.13129 RPM 6.3866 8.9319 7.70517 RPD 6.755 9.0328 8.06336 FET 1.9946 18.6935 12.1156 First Last Nsam Reading Reading 123 12089 12150 41 12130 12150 123 12089 12150 111 12095 12150 111 12095 12150 111 12095 12150 111 12095 12150 111 12095 12150 First Reading For Entire File .......... 12089 Last Reading For Entire File ........... 12150 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 16 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 12150.0 14269.0 RPM 12150.0 14269.0 RPS 12150.0 14269.0 RPX 12150.0 14269.0 GR 12150.0 14262.0 FET 12152.0 14269.0 ROP 12153.0 14309.5 $ LOG HEADER DATA DATE LOGGED: 19-SEP-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.06 DOWNHOLE SOFTWARE VERSION: PCD 3.01E DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 14310.0 TOP LOG INTERVAL (FT) : 12150.0 BOTTOM LOG INTERVAL (FT) : 14310.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 32.5 MAXIMUM ANGLE: 44.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA TOOL NUMBER P0997GR4 P0997GR4 OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 6.000 6.0 KCL POLYMER 12.30 52.0 8.3 12500 3.9 1.100 .498 .340 1.400 162.8 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 16 API 4 1 68 4 2 RPX MWD 16 OHMM 4 1 68 8 3 RPS MWD 16 OHMM 4 1 68 12 4 RPM MWD 16 OHMM 4 1 68 16 5 RPD MWD 16 OHMM 4 1 68 20 6 ROP MWD 16 FT/H 4 1 68 24 7 FET MWD 16 HOUR 4 1 68 28 8 First Name Min Max Mean Nsam Reading DEPT 12150 14309.5 13229.8 4320 12150 GR 40.7306 122.787 93.8966 4225 12150 RPX 3.6665 295.956 9.9173 4239 12150 RPS 4.8773 150.524 9.35453 4239 12150 Last Reading 14309.5 14262 14269 14269 RPM 4.6315 128.001 8.68505 4239 RPD 4.8955 194.115 9.61836 4239 ROP 2.68 262.74 57.0578 4314 FET 1.311 96.3045 10.9603 4235 12150 14269 12150 14269 12153 14309.5 12152 14269 First Reading For Entire File .......... 12150 Last Reading For Entire File ........... 14309.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/01/15 Origin ................... STS Tape Name ................ UNK/~OWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 99/01/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File