View Details... Event. In Progress. Dev Completion - Cased. Hole 09/30/2013

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Lucas Richardson
6 years ago
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1 Event In Progress CAMERON-7 Hole 09/30/2013 Dev Completion - Cased Daily Summary CAMERON 7 WOC-Chuck Pannell Daily Cost=$9700 Cum Cost=$ MIRU Halliburton wireline. RIH and log CNL, CCL, GR, CBL. RDMO wire line. SIW & SDFN PBTD=11944'. Main pass had 1000 psi, Total Cost for 09/30/2013 $11, /07/2013 Wireline - Perforate Frac - Acid Wireline - Perforate Wireline - Bridge Plug - Composite - Set Wireline Well was pre prepped ,08:00-09:00 R/U wireline. Perf Stage #1, Atoka zone. w/ 3 3/8'' 210 MaxForce expendable gun loaded w/ EXP T Super Deep penetrating charges, 21g per charge. 0.43'' EHD 60deg phasing,. Perforated 11,866 to 11,872, 11,936 to 11, intervals w/ 4 spf. Total shots 48, 48 shots fired. Correlated to HSE GR/CCL/CBL log dated :14-10:20 Frac stage #1, Atoka zone. Break down, bpm. Pumped 2500 gals 15% HCL acid. Pump 75,24 gals linear prepad. Pump 25,665 gals Hybor G X- linked pad. 32,315 gal Hybor G X- link w/ 21,804 #,30/50 CRC, and 32,315 gal Hybor G X- link w/ 53,463 # 20/40 CRC. 1000gal 15% HCL acid, 9047 gals linear flush. Max rate- 50 bpm, Avg. rate- 49 bpm, Max psi psi, Avg psi- 5915, ISIP psi, Total load to recover- 106,115 gals 10:30-11:07 R/U wireline to Perf Stage #2, Strawn zone. Set Peak Prodrill Flow thru frac 11,170' w/ 3 3/8'' 210 MaxForce expendable gun loaded w/ EXP T Super Deep penetrating charges, 21g per charge. 0.43'' EHD 60deg phasing,. Perforated ' to 11,112', 11,042 '- 11,048'. 2 intervals w/ 4spf. Total shots 48, 48 shots fired. Correlated to HSE GR/CCL/CBL log dated Set Peak Prodrill Flow thru frac 11,170' Frac - Acid 11:20-13:08 Frac stage #2, Strawn zone. Break down, bpm. Pump 5273 gals linear prepad. Pump 26,639 gals Hybor G X- linked pad w/2000 # 30/50 CRC sand slug. 28,529 gal Hybor G X- link w/ 23,763 lbs 30/50 CRC, and 17,454 gal Hybor G X- link w/ 30,384 lbs 20/40 CRC. 1000gal 15% HCL acid, 9717 gals linear flush. Max rate- 50 bpm, Avg. rate- 50 bpm, Max psi psi, Avg psi- 5678, ISIP psi, Total load to recover- 88,637 gals. Note during end of 2ppg sand stage,pressure started to increase, 2 ppg was finished, but no 3ppg was ran, well was successfully flushed, and we were able to move on. Wireline - Perforate 13:18-14:40 R/U wireline to Perf Stage #3, Lower wolfcamp zone psi shut in run Peak Prodrill solid core frac plug 10, 930' w/ 3 3/8'' 210 MaxForce expendable gun loaded w/ EXP T Super Deep penetrating charges, 21g per charge. 0.43'' EHD 60deg phasing,. Perforated 10,870 to 10,876, 10,788'to 10, intervals w/ 4spf. Total shots 48, 48 shots fired. Correlated to HSE GR/CCL/CBL log dated Wireline - Bridge Plug - Composite - Set Wireline 6100 psi shut in run Peak Prodrill solid core frac plug 10, 930' Frac - Acid Frac Stage 3: Lower Wolfcamp. 14:50-15:50 RU Halliburton frac zone 3. Break down at 5 bpm. Pump 7,843 gals linear prepad, pump 24,210 gal, Water Frac G pad, Pump 6,611# Ottawa-30/50, with 14,046 gal, Hybor G-R, followed with 93,397 # Ottawa-20/40, with 48,168 gal, Hybor G-R, 9299 gal Treated Water Flush. Max rate= 51 bpm, Avg rate= 49 bpm, Max psi= 4430 psi, Avg psi= 3706 psi, ISIP= 3043 psi. Total load= 104,602 gal.

2 Wireline - Perforate Perforate Stage 4: Middle Wolfcamp. 16:05-16:55 RU Halliburton Wireline, RIH,Set Peak Prodrill Flow thru frac 10, 300' w/ 3 3/8'' 210 MaxForce expendable gun loaded w/ EXP T Super Deep penetrating charges, 21g per charge. 0.43'' EHD 60deg phasing,. Perforated 10,236 to 10,248, intervals w/ 4spf. Total shots 48, 48 shots fired. Correlated to HSE GR/CCL/CBL log dated Wireline - Bridge Plug - Composite - Set Wireline RIH,Set Peak Prodrill Flow thru frac 10, 300' Frac - Acid Frac Stage 4: Middle Wolfcamp. 17:00-18:20 RU Halliburton frac zone 3. Break down at 1959@ 5 bpm. Pump 4711 gals linear prepad, pump 24,893 gal, Water Frac G pad, Pump 6,731 # Ottawa-30/50, with 14,041 gal, Hybor G-R, followed with 100,029 # Ottawa-20/40, with 48,050 gal, Hybor G-R, 8,889 gal Treated Water Flush. Max rate= 40 bpm, Avg rate= 40 bpm, Max psi= 2911 psi, Avg psi= 2513 psi, ISIP= 2072 psi. Total load= 102,212 gal. Wireline - Perforate 17:30-18:00 Perforate Stage 5: Upper Wolfcamp. 18:30-19:39 RU Halliburton Wireline, RIH,Set Peak Flow thru Prodrill frac 10, 070' w/ 3 3/8'' 210 MaxForce expendable gun loaded w/ EXP T Super Deep penetrating charges, 21g per charge. 0.43'' EHD 60deg phasing,. Perforated 10,020 to 10,024, 9,962 to 9,966, 9,926' to 9,930', intervals w/ 4spf. Total shots 48, 48 shots fired. Correlated to HSE GR/CCL/CBL log dated SDFN Wireline - Bridge Plug - Composite - Set Wireline, RIH,Set Peak Flow thru Prodrill frac 10, 070' Daily Summary Cameron # 7 WOCS: Denson Crabtree Halliburton (Rigless) Daily Cost = $ 61, Cumulative Cost = $ 71, Fraced & perforated stages 1-4, perforated stage 5, Stage 4 was cut short at the end of 2ppg due to formation pressure, 75 % of Sand was placed, and stage successfully flushed. fraced remaining stages to 100% of engineered design. Well was pre prepped and ready to frac, asset engineer was not on location for frac. Remaining stages will be completed Total Cost for 10/07/2013 $7, /08/2013 Daily Summary CAMERON 7 WOCS: CHUCK PANNELL Daily Cost: $427, Cumulative Cost: $446, /08/ Well completed. All stages completed per design. All qa/qc docs received. Chemicals /sand inventory verified. Fluid tests witnessed. Well was prepped. Asset engineer watching from Houston. RDMO to SOUTH CURTIS RANCH. NDP: Frac - Acid Frac Stage 5. RU HALLIBURTON FRAC. Break down at bpm. Pump 3027 gal 15% Acid. Pump gal Treated Water Pre Pad, Pump gal 15# Hybor R Pad, Pump gal 15# Hybor R w/ # 20/40 & 30/50 Ottawa Prop. Pump 1004 gal 15% Acid, Pump 8705 gal Treated Water Flush. Max rate= 51 bpm, Avg rate= 50 bpm, Max psi= 3817 psi, Avg psi= 3538 psi, ISIP= 2368 psi. Total load= gal. Wireline - Perforate Perf Stage 6. RU HALLIBURTON WIRELINE. Set FLO THRU 9870'. Perf stage w/ 3 3/8" 60 deg phasing gun Total shots= 48 & fired= 48. Net feet = 12'. Wireline - Bridge Plug - Composite - Set Wireline Set FLO THRU 9870' Frac - Acid Frac Stage 6. RU HALLIBURTON FRAC. Break down at bpm. Pump 4866 gal Treated Water Pre Pad, Pump gal 15# Hybor R Pad, Pump gal 15# Hybor R w/ # 20/40 & 30/50 Ottawa Prop. Pump 1023 gal 15% Acid, Pump 8423 gal Treated Water Flush. Max rate= 41 bpm, Avg rate= 40 bpm, Max psi= 3375 psi, Avg psi= 2812 psi, ISIP= 2321 psi. Total load= gal.

3 Wireline - Perforate Perf Stage 7. RU HALLIBURTON WIRELINE. Set FLO THRU 9590'. Perf stage w/ 3 3/8" 60 deg phasing gun Total shots= 48 & fired= 48. Net feet = 12'. Wireline - Bridge Plug - Composite - Set Wireline Set FLO THRU 9590' Frac Frac Stage 7. RU HALLIBURTON FRAC. Break down at bpm. Pump 5317 gal Treated Water Pre Pad, Pump gal 15# Hybor R Pad, Pump gal 15# Hybor R w/ # 20/40 Ottawa Prop. Pump 1046 gal 15% Acid, Pump 7910 gal Treated Water Flush. Max rate= 52 bpm, Avg rate= 50 bpm, Max psi= 3281 psi, Avg psi= 2853 psi, ISIP= 2183 psi. Total load= gal. Wireline - Perforate Perf Stage 8. RU HALLIBURTON WIRELINE. Set FLO THRU 9070'. Perf stage w/ 3 3/8" 60 deg phasing gun Total shots= 48 & fired= 48. Net feet = 12'. Wireline - Bridge Plug - Composite - Set Wireline Set FLO THRU 9070' Frac - Acid Frac Stage 8. RU HALLIBURTON FRAC. Break down at bpm. Pump 5461 gal Treated Water Pre Pad, Pump gal 15# Hybor R Pad, Pump gal 15# Hybor R w/ # 20/40 Ottawa Prop. Pump 8711 gal Treated Water Flush. Max rate= 31 bpm, Avg rate= 30 bpm, Max psi= 1849 psi, Avg psi= 1289 psi, ISIP= 1211 psi. Total load= gal. Total Cost for 10/08/2013 $427, /22/2013 Daily Summary 10/22/13 Nabors 672 Cameron #7 Jim Birkenfeld Daily cost 5,525 Accumulated cost 452,452 Held tailgate safety meeting. Spot pulling unit. Had to leave location due to bees. Rig up pulling unit. Well open to reserve pit. NDP run bit. Pulling Unit - Move/Camp Move pulling unit from Pamela 5 to Cameron 7 Pulling Unit - Rig Up Waiting on Orders Pulling Unit - Rig Up Spot pulling unit shut down due to bees Wait on sworm on bees to move on Rig up pulling unit Well open to reserve pit Total Cost for 10/22/2013 $5, /23/2013 Daily Summary 10/23/13 Nabors 672 Cameron #7 Jim Birkenfeld Daily cost 84,480 Accumulated cost 536,932 Held tailgate safety meeting. Open well casing 0 psi. Function test hydraulic BOP. Nipple down FRAC stack nipple up hydraulic BOP. Pickup new 4 ¾ skirted bit 4-3 ½ drill collars 252 joints 2 7/8 l80 bit at 8,005 feet. NDP drill plugs. BOPE - Function Test Frac Valve - Nipple Down Casing 0 psi Function test hydraulic BOP Nipple down frac stack

4 BOPE - Nipple Up Bit - Run Nipple up hydraulic BOP Pickup new 4 3/4 bit 4-3 1/2 drill collars 40 joints 2 7/8 L80 tubing Bit - Run Pickup 217 joints 2 7/8 L80 tubing bit at 8,005 Secure well close & lock BOP close all valves Total Cost for 10/23/2013 $84, /24/2013 Daily Summary 10/24/13 Nabors 672 Cameron #7 Jim Birkenfeld Daily cost 21,405 Accumulated cost 558,337 Held tailgate safety meeting. Open well casing 150 psi tubing 50 psi. Pump 120 BBLS brine down tubing well on vacuum. Nipple up stripper head plum stripper to flow back pit with 2 inch steel line. Break circulation with foam air unit. Run 12 joints 2 7/8 tubing tag 9,056 feet. Rig up power swivel. Break circulation clean out to 9,577 feet circulate 2 hours. Rig down power swivel. Pull 52 joints 2 7/8 tubing bit at 8,005. NDP drill plugs. Safety - Personnel Marco Gonzalez OP W, Dustin Vyoral DH W, Saul Rivera FH W, Edgar Corona FH W Crew drove to location Well Control - Bleed Well Down Well Control - Kill Well Stripper Head - Nipple Up/Nipple Down Circulate Held JSA Meeting 50 pis 150 psi Bleed well down Pump 120 bbls down TBG NU stripper head Break circulation w/air unit Bit - Run RIH w/12-2 7/8" TBG, tag 9056' Power Swivel - Rig Up RU swivel Drill Drill out plug, drill out to 9577' Circulate Well Control - Kill Well Power Swivel - Rig Down Bit - Pull Circulate clean Pump down TBG RD swivel POOH w/52-2 7/8" TBG Secure location Crew drove home Total Cost for 10/24/2013 $22, /25/2013 Daily Summary 10/25/13 CAMERON 7 NABORS 672 WOC: CHRIS WINTER DAILY COST: $ 25, ACCUMULATED COST: $ 584, ACTIVITY: Crew drove to location. Held JSA Meeting. Check well pressures - TBG 450 psi CSG 150 psi. Wait on Wellfoam. Break circulation w/air unit. RIH w/52-2 7/8" TBG, tag 2nd plug at 9572'. RU swivel. Drill out 2nd plug. RIH w/9-2 7/8" TBG, tag 3rd at 9885', drill out. RIH w/6-2 7/8" TBG, tag 4th plug at 10079', drill out. RIH w/8-2 7/8" TBG, tag 5th plug at 10315', drill out. Circulate clean. Pump 50 bbls down TBG. RD swivel. POOH w/76-2 7/8" TBG. SION.

5 Waiting on Service Provider Circulate NDP - BREAK CIRCULATION, RIH W/BIT, DRILL OUT TO PBTD, CIRCULATE CLEAN, POOH W/BIT Crew drove to location Crew held JSA meeting 450 psi 150 psi Waiting on Service Provider - Wellfoam. Wellfoam unit needed something welded on, they took it into the shop the night before, didn't not arrive on location till 9:30am Break circulation w/air unit Bit - Run RIH w/52-2 7/8" TBG, tag 2nd plug at 9572' Power Swivel - Rig Up Drill Circulate Well Control - Kill Well Power Swivel - Rig Down Bit - Pull RU swivel Drill out 2nd plug. RIH w/9-2 7/8" TBG, tag 3rd at 9885', drill out. RIH w/6-2 7/8" TBG, tag 4th plug at 10079', drill out. RIH w/8-2 7/8" TBG, tag 5th plug at 10315', drill out. Circulate clean Pump 50 bbls down TBG RD swivel POOH w/76-2 7/8" TBG Secure location Crew drove home Total Cost for 10/25/2013 $25, /28/2013 Daily Summary 10/28/13 Cameron #7 Nabors 672 Jim Birkenfeld Daily cost 25,702 Accumulated cost 583,864 Held tailgate safety meeting. Open well casing 800 psi tubing 500 PSI. Run in tag plug 10,930. Rig up power swivel. Break circulation drill 2 plugs clean out to TD 11,944 circulate 3 hours clean. Rig down power swivel. Pull 126 joints 2 7/8 L80 tubing. NDP pull bit run gyro. Bit - Run Power Swivel - Rig Up Drill Power Swivel - Rig Down Bit - Pull Casing 800 psi Tubing 500 psi Run bit tag 10,930 feet Rig up power swivel Drill 2 plugs clean out to 11,944 circulate 3 hours Rig down power swivel Pull 126 joints 2 7/8 tubing Secure well close & lock BOP close all valves Total Cost for 10/28/2013 $26, /29/2013

6 Daily Summary 10/29/13 Cameron #7 Nabors 672 Jim Birkenfeld Daily cost 16,805 Accumulated cost 626,654 Held tailgate safety meeting. Open well casing 800 psi tubing 500 psi. Pump 45 BBLS brine down tubing 80 BBLS brine down casing trickle brine down casing ½ BBL per minute. Pull 252 joints 2 7/8 tubing lay down drill collars & 4 ¾ bit. Rig up scientific run gyro. Run 100 joint kill string. NDP run packer pump chemical squeeze. Well Control - Kill Well - Brine Tubing - Pull Wireline - Logging Tubing - Run Casing 800 psi Tubing 500 psi Pump 45 bbls brine down tubing 80 bbls brine down casing Pull 252 joints 2 7/8 tubing lay down drill collars Run gyro Run 100 joint kill string Secure well close & lock BOP close all valves Total Cost for 10/29/2013 $16, /30/2013 Daily Summary 10/30/13 Cameron #7 Nabors 672 Jim Birkenfeld Daily cost 12,955 Accumulated cost 639,609 Held tailgate safety meeting. Open well casing100 psi tubing 50 psi. pump 20 BBLS brine down tubing 150 BBLS brine down casing. Pull 100 joints 2 7/8 tubing. Pickup 5 ½ X 2 7/8 crest three packer run on 324 joints 2 7/8 tubing set packer 10,131. Pump chemical squeeze 15 gallons 9157A with 25 BBLS fresh water 80 gallons 6490A with 50 BBLS fresh water flush with 300 BBLS fresh water with 10 gallons 6106A pump at 2 BBLS per minute 1,500 psi. NDP pull packer run RBP & packer pump chemical. Well Control - Kill Well - Brine Tubing - Pull Packer - Run Chemical Treatment - Scale Squeeze Casing 100 psi Tubing 50 psi Pump 30 BBLS brine down tubing 150 BBLS brine down casing Pull 100 joints 2 7/.8 tubing Run 5 1/2 X 2 7/8 crest three packer on 324 joints 2 7/8 tubing set packer 10,131 Pump scale squeeze per brief Close & lock BOP close all valves

7 Waiting on Service Provider Total Cost for 10/30/2013 $12, /31/2013 Daily Summary 10/31/13 Cameron #7 Nabors 672 Jim Birkenfeld Daily cost 18,775 Accumulated cost 658,384 Held tailgate safety meeting. Open well tubing 600 psi casing 50 psi. Bleed off well pump 60 BBLS brine down tubing. Pull 324 joints 2 7/8 tubing lay down packer. Shut down due to wind. NDP run RBP & packer pump chemical. Well Control - Kill Well - Brine Packer - Pull Packer - Pull Tubing 600 psi Casing 0 psi Bleed off well pump 60 BBLS brine down tubing Release packer pull 200 joints 2 7/8 tubing Pull 124 joints 2 7/8 tubing lay down packer Shut down due to wind close & lock BOP Total Cost for 10/31/2013 $18, /01/2013 Daily Summary 11/1/13 Cameron #7 Nabors 672 Jim Birkenfeld Daily cost 14,805 Accumulated cost 673,190 Held tailgate safety meeting. Open well casing 0 psi. Pickup 5 ½ cline RBP 5 ½ crest packer run on /8 tubing. Set RBP 10,128 pull one joint set packer test RBP 500 psi ok. Pull packer up to 8,946 feet 286 joints 2 7/8 tubing. Pump chemical squeeze per brief. NDP pull packer & plug. Packer & Plug - Run Casing 0 psi Run 5 1/2 RBP 5 1/2 packer 324 joints 2 7/8 tubing Packer - Set Set RBP 10,128 test 500 psi ok set packer 8,946 Chemical Treatment - Scale Squeeze Pump scale squeeze per brief Secure well close & lock BOP close all valves Total Cost for 11/01/2013 $14, /04/2013 Daily Summary 11/4/13 Cameron #7 Nabors 672 Jim Birkenfeld Daily cost 8,685 Accumulated cost 681,875 Held tailgate safety meeting. Open well casing 550 psi tubing 600 psi. Bleed well off. Open by pass on packer. Circulate 250 BBLS brine down tubing casing flowing. Wait 1 hour well did not die. Circulate 250 BBLS brine

8 Well Control - Bleed Well Down Well Control - Kill Well - Brine Well Control - Bleed Well Down Well Control - Kill Well - Brine Well Control - Bleed Well Down Packer - Unseat Packer - Pull casing dead tubing flowing wait 1 hour well dead. Release packer run in release RBP. Pull 50 joints 2 7/8 tubing. NDP pull packer. Casing 550 psi Tubing 600 psi Bleed off casing & tubing Open by pass on packer circulate 250 BBLS brine Casing flowing tubing dead flow back 1 hour Circulate m 250 BBLS brine casing on vacuum tubing flowing Flow tubing 1 hour well dead Release packer run in release RBP Pull packer & RBP above perforation Close & lock BOP casing open to reserve pit through choke manifold Drive drew to location Total Cost for 11/04/2013 $10, /05/2013 Daily Summary 11/5/13 Cameron #7 Nabors 672 Jim Birkenfeld Daily cost 15,545 Accumulated cost 673,190 Held tailgate safety meeting. Open well casing 0 psi tubing 0 psi. Pull 286 joints 2 7/8 tubing lay down packer & RBP. Pickup BHA run production tubing. 354 joints 2 7/8 L80 tubing one 2 7/8 X 4 foot marker sub 2 jionts 2 7/8 L80 tubing 0ne 5 ½ X 2 7/8 TAC 6 joints 2 7/8 L80 tubing one 2 7/8 MDN seating nipple one 12 slot sand screen one 2 7/8 mud anchor with bull plug. Bull plug 11,751 seating nipple 11,693 TAC 11,435. Set hydraulic TAC. NDP pull standing valve run rods. Packer - Pull Tubing - Run Tubing Anchor - Set casing 0 psi Tubing 0 psi Pull 286 joints 2 7/8 lay down packer & RBP Run production tubing Set hydraulic TAC Claoe & lock BOP close all valves Total Cost for 11/05/2013 $15, /06/2013 Daily Summary 11/6/13 Cameron #7 Nabors 672 Jim Birkenfeld Daily cost 11,515 Accumulated cost 708,935 Held tailgate safety meeting. Casing 0 psi tubing 0 psi. Nipple down hydraulic BOP nipple B1 adapter with 10 points puller into hydraulic TAC. Wait 4 ½ hours on pardon for spreader bar. Unload rods. NDP Pickup pump & rods.

9 BOPE - Nipple Down Wellhead - Nipple Up Standing Valve - Fish Waiting on Service Provider Equipment - Load/Unload Casing 0 psi Tubing 0 psi Nipple down hydraulic BOP Nipple up B1 adaptor with 10 points tension pulled in TAC Wire line fish standing valve Norris & pradon did not have spreader bar Unload rods Close all valves Total Cost for 11/06/2013 $11, /07/2013 Daily Summary 11/7/13 Cameron #7 Nabors 672 Jim Birkenfeld Daily cost 39,815 Accumulated cost 748,750 Held tailgate safety meeting. Open well casing 0 psi tubing 0 psi. Pickup 2 ½ X 1 ¼ X 24 foot pump 14-1 ½ sinker bars ¾ Norris 97 rods 47 - ¾ Norris 97 with 4 guides per rod ¾ Norris 97 rods 29-7/8 - Norris rods with 4 guides per rod 20-7/8 Norris 97 rods. NDP finish running rods. Safety - Personnel Waiting on Service Provider Pump/Rods - Run Pump/Rods - Run Polish Rod - Install Marco Gonzalez OP W, Matthew Hernandez DH W, Xavier Melgoza FH W, Saul Rivera FH W, Cruz Valles FH G Crew drove to location Held JSA Meeting 0 psi 0 psi NORRIS - Did not bring torque card for rods Pick up and RIH w/1.25"x24' pump, " k sinker bars w/sht couplings w/necks, 122-3/4" N97 rods, 47-3/4" N97 guided rods 4- per rod Crew ate lunch Held JSA Meeting Continue RIH w/179-3/4" N97 rods, 29-7/8" N97 guided rods 4 per rod, 20-7/8" N97 rods Install PR Secure location Crew drove home Total Cost for 11/07/2013 $39, /08/2013 Attending oxy safety meeting

10 Rods - Run Pumping Unit - Hang on Head Pump - Longstroke Reviewed JSA plan 0 psi 0 psi Picked up 52 7/8 rods. Subs: 8', 6', 2'. Raise workfloor and pick up polish rod Install horsehead Pressure up tbg to 500 psi Long stroke well. Pressure up pump to 500 psi Pump - Space Out Space out pump 36" Pulling Unit - Rig Down rig down and clean location Drove crew back home Total Cost for 11/08/2013 $2, Total Cost for CAMERON-7 $752,234.17

CNL, CCL, GR, CBL. RDMO

Event Waiting on Tour Sheet CARRIE-18WD Hole 11/16/2013 Dev Completion - Cased Wireline - Logging 11-16-13 -MIRU Halliburton wireline. RIH and log CNL, CCL, GR, CBL. RDMO wire line. SIW & SDFN PBTD=6068.