Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
2014 Oooguruk Unit
j9 C° C CA -PLUS Energy Alaska March 31, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 Dale Hoffman, CPL M,an,oer, (_and and Externa! Affairs a L.�1rJfIii3o.ii usenelQVy Codi Direct: 108 Ce,!;; 9ii;-830-?571 Annual Reservoir Surveillance Reports 2015 — Oooguruk Unit Oooguruk-Kuparuk, Oooguruk-Nuigsut and Oooguruk-Torok Oil Pools Dear Commissioner Foerster: VAR 3 1 2015 The Alaska Oil and Gas Conservation Commission (AOGCC) approved pool rules for the Oooguruk-Kuparuk, Oooguruk-Nuiqsut and Oooguruk-Torok pools within the Oooguruk Unit as Conservation Orders 596, 597 and 645, respectively. Rule 9 of the orders requires the filing of annual surveillance reports, which are attached hereto. We will schedule a meeting with AOGCC staff in the future to discuss the reports. Please let us know if you have any questions or require additional information regarding the attached. Sincerely, Dale Hoffman Attachments C CAELUS ,# Alaska Annual Reservoir Surveillance Report Oooguruk-Nuiqsut Oil Pool Oooguruk Field April 1, 2015 Table of Contents SUBJECT PAGE 1.0 Progress of the Enhanced Recovery Project................................................................ 3 2.0 Results and Analysis of Reservoir Pressure Surveys within the Pool ....................... 4 3.0 Results and Analysis of Production and Injection Log Surveys, Tracer Surveys, Observation Well Surveys and Any Other Special Monitoring ................................... 4 4.0 Review of Pool Production Allocation Factors and Issues Over the Year .................. 4 5.0 Reservoir Management Summary................................................................................. 5 ATTACHMENTS............................................................................. Error! Bookmark not defined. ATTACHMENT A: Voidage Balance by Month of Produced Fluids and Injected Fluids 2014 6 ATTACHMENT B: Map of Nuiqsut Well Locations................................................................. 7 ATTACHMENT C: Form 10-412 Pressure Report for Nuiqsut ................................................ 8 ATTACHMENT D: Nuiqsut Reservoir Pressure Map — 2014 .................................................. 9 1.0 Progress of the Enhanced Recovery Project At the end of 2014 there were 21 active Oooguruk-Nuiqsut oil pool (ONOP) development wells in the Oooguruk Unit (OU), including 14 producers and seven injection wells. An additional three wells, ODSN-03i, ODSN-42B and ODSN-43, are in progress and will be completed using mechanical diversion hydraulic fracture stimulations during the winter 2015 ice season. The locations of existing Nuiqsut wells are shown on Attachment B. During 2014 four wells, ODSN-03i, ODSN-19, ODSN-43, and ODSN-48i were drilled. Four wells, ODSN-02, ODSN-04, ODSN-28 and ODSN-48, were fracture stimulated and placed on production during 2014. A re-fracture stimulation treatment was conducted in ODSN-24 and high pressure breakdown stimulations were completed in five injection wells. Additionally, four rig workovers were conducted in 2014. Within the Kalubik fault block, ODSN-01, ODSN-24, ODSN-25, ODSN-31, ODSN-36 and ODSN-37 continued to produce in 2014. The wells are supported by water and gas injection in ODSN-26i, ODSN-32i, and ODSN-34i. The ODSN-19i well was drilled and completed in 2014 and will be converted to injection in 2015. ODSN-16, ODSN-17 and ODSN-18 continued to produce throughout 2014 in the Colville Delta fault block, supported by water and gas injection in ODSN-23i and ODSN- 15i. In the Ivik fault block ODSN-29 continued producing in 2014 and production was initiated from ODSN-02, ODSN-04 and ODSN-28. These new extended reach wells (19,239 ft MD to 21,534 ft MD), are the most productive wells in the ONOP to -date. They were completed with staged, mechanical diversion hydraulic fracture treatments with horizontal laterals ranging from approximately 6,400 ft to 6,900 ft. Following a post- fracture clean-up period, production from the block has been proactively restricted by Caelus to minimize gas/oil ratio (GOR) increases until additional injection is initiated. The wells are currently supported by ODSN-27i; ODSN-03i, drilled in 2014 and to be completed in 2015, will provide additional injection in the block. ODSN-03i is planned to be the first ONOP injection well completed with a staged mechanical diversion hydraulic fracture treatment, similar to the prolific production wells in the block. The completion is expected to significantly improve injection relative to existing injection completions. In 2014 OU seawater injection was interrupted by Kuparuk River Unit (KRU) seawater flowline corrosion repairs. OU receives seawater from the KRU Seawater Treatment Plant (STP) via the KRU Central Production Facility 3 (CPF3). The KRU 10 in. flowline from CPF3 to OU was shut in for corrosion anomalies on March 24, 2014. KRU implemented a temporary seawater flowline route allowing OU to re-establish injection on September 10, 2014. OU was without seawater injection supply for this 170 -day period. Annual average daily ONOP production during 2014 was 10,447 BOPD. Cumulative oil production from the ONOP during 2014 was 3,813 MBO and is 10,001 MBO since field start-up. Annual average daily ONOP injection during 2014 was 3,387 BWPD and 4,159 Mscfd. Cumulative water injection in the ONOP during 2014 was 1,236 MBW and 6,842 MBW Caelus Natural Resources Alaska, LLC Page 3 since the start of the project. Cumulative gas injection in the ONOP during 2014 was 1,518 MMscf and 3,957 MMscf since the start of the project. During 2014, water and gas injection continued in the Oooguruk-Nuiqsut oil pool. Offset producing wells have seen GOR stabilization and arrest of production declines; water breakthrough has not occurred. Attachment A details the 2014 monthly voidage for the ONOP. 2.0 Results and Analysis of Reservoir Pressure Surveys within the Pool Twenty-five pressure surveys were completed in eighteen wells. Initial static pressure surveys were completed in the four new Nuiqsut wells, ODSN-02, ODSN-04, ODSN-28 and ODSN-48i, in 2014. The details of the pressure tests and interpretation can be found in Attachments C and D. 3.0 Results and Analysis of Production and Injection Log Surveys, Tracer Surveys, Observation Well Surveys and Any Other Special Monitoring Well surveillance equipment was placed in the production liners of ODSN-28 and ODSN-48 to assess oil and water production conformance along the lateral via target fluid tracers, which were monitored and analyzed by collecting surface fluid samples over time. These data confirmed the effectiveness of the staged mechanical diversion hydraulic fracture stimulations showing relatively uniform contributions along the entire laterals. The tracers have also been used to periodically assess hydraulic connectivity along the lateral to evaluate the need for coil tubing intervention to clear any sand or debris blocking the flow path. 4.0 Review of Pool Production Allocation Factors and Issues Over the Year Production from the Oooguruk-Nuiqsut, Oooguruk-Kuparuk and Oooguruk-Torok pools is commingled at the surface into a common production line. Allocation between the pools is based on ratio of total production for a pool to the total production for the Oooguruk Unit. The pool allocation factors for 2014 are: Oooguruk-Nuiqsut Pool: 92.13% Oooguruk-Kuparuk Pool: 5.54% Oooguruk-Torok Pool: 2.33% Theoretical production for individual wells for all pools is calculated on a daily basis. During 2014 most wells, excluding the Ivik fault block, were produced with chokes at 100% open due to the capacity of the production line. Daily theoretical production for a well was calculated using the data from the most current well test and the amount of time a well was on production for a given day: Caelus Natural Resources Alaska, LLC Page 4 Min i t tes produced 1440 Minutes day xDailyRate(BOPD),,.e,,,,, = TheoreticalDailyProduction The daily allocation factor for the unit is calculated by dividing the actual total production for the day by the sum of the theoretical daily production for each individual well. Daily allocated production is assigned to each well by multiplying its theoretical daily production by the daily allocation factor. The average daily allocation factor for 2014 was 1.0289. 5.0 Reservoir Management Summary The Alaska Oil and Gas Conservation Commission (AOGCC) issued pool rules under Conservation Orders No. 645, 596 and 597 for the Oooguruk-Torok, Oooguruk-Kuparuk and Oooguruk-Nuiqsut reservoirs, respectively. Subsurface development of the Oooguruk Unit is done with dedicated development wells to the Oooguruk-Torok, Oooguruk-Nuiqsut and Oooguruk-Kuparuk oil pools with no subsurface commingling. Unitized substances produced from the three oil pools are commingled on the surface. Area injection orders authorizing the injection of fluids for enhanced oil recovery in the Oooguruk-Kuparuk and Oooguruk-Nuiqsut reservoirs were issued by the AOGCC as Area Injection Orders No. 33 and 34, respectively. Injection commenced into both pools in 2009. At the end of 2014 there were 21 active ONOP wells, including 14 producers and seven injection wells. An additional three wells are in progress and will be completed using mechanical diversion hydraulic fracture stimulations during the winter 2015 ice season. The focus in 2015 will be to increase voidage replacement in all fault blocks by drilling new injection wells, converting existing pre -produced injectors, ODSN-19i and ODSN- 48i, and completing high pressure breakdown treatments on existing injection wells. Additionally, the ODSK-42A surface slot and surface casing will be salvaged to efficiently drill, fracture and test the Nuiqsut in an untested area of the eastern Kalubik fault block near well control (both ODSK-42 and ODSK-42A were drilled through the Nuiqsut). Caelus Natural Resources Alaska, LLC Page 5 r v r O N LL m AV W Zi i N r-,LL v 0 L (L 4- 0 s c C0 G :.i c m (a W cu z m m a is N m no C � cwt N rl try Ci O C1 M �-i rl h N rl 2 0:! CC 6A O U7 rl N t71 VR O Ln Q� M 7 CJ 0 Cfi M p 1t) 40 m V Iia V�j N a 4 �a eezz7l pp �-c ��pp CO m „ep�fy -1 eq NeMl w ��V�,ryry1 W N � OF I 3 H N r-1 ri ri � rl r) V Q •� G A Ln 47 r-' C _o 9 � ;2 co op N Q y cu z m m a is N m no w w o i 40 Oft 0 m 0 Cfi M p 1t) 40 m V Iia V�j N 4 �a eezz7l pp v��l ��pp „ep�fy -1 eq NeMl yNyy� ��V�,ryry1 3 H N r-1 ri ri rl r) V •� G A Ln Gml_. r-' 9 � ;2 co N Q y 4J m m v eryV u�sy N CL eh ch 0722O g Cv N u�'1 P. tla n M1 n 9 > u5 O u C `o E gO N U) w N r -I 0 u. N O U O � cu in N I!'f M1 M p 1t) 40 m Iia V�j N 4 -1 eq NeMl yNyy� ��V�,ryry1 3 r-1 ri ri rl r) V Ln Gml_. r-' N Q 4J m m eryV u�sy N c�nl eh ch 0722O g Cv N u�'1 P. tla n M1 n 9 > gO N U) w N r -I 0 O N O O O � O(D d ACNnV7 O� A pppp m Q).q N 2 M .q 0 N m W O 2 L -M Q :," '-I N u'1 R 3 Ill �1 d' [f M � ate+ N N fl m� tw 6. t � a oz°a v V � ATTACHMENT B: Map of Nuiqsut Well Locations d AD1-389956`��� �y� ADL38995� - s o2 ,,o SN -0 \ A�2�9301 AbC389960 Ani 959 ODSN- ADL 58 t " ODSN-010DSN Bi O SN�9i DSN- 7i 0 D z L389954 )1-389t3\ D N2 o' N-3 I ODS�',I- - N36 '�.. ODSN-I' �L38995 ADL389949 DSN-2 ADL355 37, � i ti 3 w `J \\ F DSN-4 99 ADL,389951 n t � Legend N ADL355039 A Nuiqsut Pool w + E Current Nuiqsut PA S Q Unit Boundary Lease Boundary Township Boundary Miles 0 0.5 1 2 3 4 O LL y r d �O rv� 5 uja � e R a o� F gg pp g 8 R FS S 2 m W a��g - aco 4 S F- S g BZW IL O m Y S 3 a 8 8 3£ E m 8 UJ m P, A 8 m m m g m 8 s n LU ii o 0 0 0 0 0 0 0 o o 3 o o 3 o o o o o o o o o s" i v O2 m8 �i 8 8 8 28 dd 8 8 74 B 8 tv 8 ctl 8 �' S' iG 8 B gg rhe �(y J t uF q � nn �' 6 pz N k 2Z 2Z 22 yy yy 2Z 2 22 Zy 2z 2Z j' ATTACHMENT D: Nuiqsut Reservoir Pressure Map — 2014 a.5W00 960000- 470000 480DOa x80000 13 16 17\. 16-`'{ l 54 13 18 17 18 24 10 \ 20 �\ 2h�r� 22 23 24 D 21 Wye kl Nulgsut Pressure PSI - 5:1000 "' " T14NR7 O3 9 3 9 ((--^-^-^� {w.l 5.351 -' 6c0 \T14Ni Q Uo9 -1sW T14 25 6E 30\ '. 2B 28 822 .. \W 1,504- LVO ODSN-A\ y [�I.WO-17U Q 1 - taco 2042 No Qt.eoc-tseo �i,9W 2CW -28 2 78 �� 31 SN -19i- 3020 33 3e O N-29 ODSN•27 d375 Q2,oW-2,500 � 2 DO 2W 6040000 `'^. COS M1 2832 1494 0 22W 2, W 21)00 40000 1876., -1404 =2.404-2.— bD5 M2.x -1604 ` ODBN- i 466 2,609-2,700 6 _ -1 4480 OCSN-37 3 2852 7 8 2190-2600 , ODSN-16L7 27Q2.800-1900 A 2541 ,� Q 2.e 3,x04 Q3000-3.100 ` SN -2 - =3,1W .31 T13 6E \ 4124 �3.2W 8030040 12 F6 7 8 \� \ 9 i��17 t 2)'�,,\\ 7 0 3.30 - 3.400 \a 3604 3.7M x e �\ J =3.704 -36M 13 18 57 ODSN-48 1B T13 7E 14 13 ©3,804-3,900 3.900 4000 1 261 T7 04.Wo-4.104 Q41W-4.200 d. N-170 Q4.2W-4,300 �2 •y 0420006 24 p��. 119 20 21 23 '}: \ 24 19 } yj Q4,600-4,700 20000 Legend 26 : 30 zs 26 2725 - 30 Nuigsut Pool Q Nuigsut PA 0 0.5 12 Miles3,3 35 , 36 31 450000 960049 470000 480000 x90000 C CAELUS Energy Alaska Annual Reservoir Surveillance Report Oooguruk-Kuparuk Oil Pool Oooguruk Field April 1, 2015 Table of Contents SUBJECT PAGE 1.0 Progress of the Enhanced Recovery Project................................................................ 3 2.0 Results and Analysis of Reservoir Pressure Surveys within the Pool ....................... 3 3.0 Results and Analysis of Production and Injection Log Surveys, Tracer Surveys, Observation Well Surveys and Any Other Special Monitoring ................................... 4 4.0 Review of Pool Production Allocation Factors and Issues Over the Year .................. 4 5.0 Reservoir Management Summary................................................................................. 4 6.0 ATTACHMENTS................................................................... Error! Bookmark not defined. ATTACHMENT A: Voidage Balance by Month of Produced Fluids and Injected Fluids.......... 7 ATTACHMENT B: Map of Kuparuk Well Locations............................................................... 8 ATTACHMENT C: Form 10-412 Pressure Report for Kuparuk............................................... 9 ATTACHMENT D: Kuparuk Reservoir Pressure Map - 2014 .................................................10 1.0 Progress of the Enhanced Recovery Project During 2014, there were no new drilling activities within the Kuparuk Pool of the Oooguruk Unit (OU). There are currently five active wells (three producers and two injectors) and three inactive wells. One inactive well, ODSK-13, within the Ivik fault block, is currently shut-in following a rig workover and subsequent production and injection testing. Another, ODSN-40, in the Colville Delta fault block, is currently shut-in due to inconsistent injection. The ODSK-42Ai well was shut-in after a short period of injection since it could not maintain consistent injection at the water injection header pressure post gel treatment in 2010. The well slot and surface casing will be reclaimed in 2015 for a Nuiqsut location in the southern Kalubik fault block. The ODSK-14 and ODSK-41 wells continued to produce throughout 2014.The ODSK-33 was shut-in most of year due high water cut; a three day test ending February 2, 2014 produced 12,733 bbls of water and two barrels of oil. The ODSK-38i and ODSK-35i wells continued injection with both injectors performing as expected and capable of replacing off take. The 2014 OU seawater injection was interrupted by Kuparuk River Unit (KRU) seawater flowline corrosion repairs. OU receives seawater from the KRU Seawater Treatment Plant (STP) via the KRU Central Production Facility #3 (CPF3). The KRU 10" flowline from CPF3 to OU was shut in for corrosion anomalies on March 24, 2014. KRU implemented a temporary seawater flowline route allowing OU to re-establish injection on September 10, 2014. OU was without seawater injection supply for this 170 -day period. Additionally, ODSK-35A water injection has been suspended following the ODSN-01 workover in July, 2014 due to the close proximity of the toe of the well to the compromised casing in the ODSN-01 well. ODSK-35A injection will be restarted upon completion of ODSN-01 workover to repair the casing in 2015. The locations of the OKOP wells are shown on Attachment B. Annual average daily Kuparuk production for 2014 was 628 BOPD. Cumulative oil production from the Oooguruk-Kuparuk Oil Pool during 2014 was 229 MBO and 8,192 MBO since field start-up. Average daily Kuparuk water injection for 2014 was 819 BWPD. Cumulative water injection in the Oooguruk-Kuparuk Oil Pool during 2014 was 299 MBW and 13,834 MBW since the start of the project. 2.0 Results and Analysis of Reservoir Pressure Surveys within the Pool Ten pressure surveys were conducted in eight OKOP wells during 2014; the pressure survey results are presented in Attachments C and D. Overall the pressures in the Kalubik fault block indicate pressure stabilization due to historical voidage replacement. Pressures from the ODSK-13 injection and fall off test indicate the Ivik block is not in hydraulic communication with the main Kalubik block development area. Caelus Natural Resources Alaska, LLC Page 3 3.0 Results and Analysis of Production and Injection Log Surveys, Tracer Surveys, Observation Well Surveys and Any Other Special Monitoring A chemical tracer program was initiated in May 2012 and completed in 2014. Tracers were injected into ODSK-35i and ODSK-38i. Within twenty months of initial injection tracer concentrations were observed in ODSK-33 and ODSK-14 from ODSK-35i. To date, ODSK-38i tracer has not been seen in any producers other than minor amounts in ODSK-33. The data will be used to evaluate future potential injection conformance alternatives. 4.0 Review of Pool Production Allocation Factors and Issues Over the Year Production from the Oooguruk-Nuiqsut, Oooguruk-Kuparuk and Oooguruk-Torok pools is commingled at the surface into a common production line. Allocation between the pools is based on ratio of total production for a pool to the total production for the Oooguruk Unit. The pool allocation factors for 2014 are: Oooguruk-Nuiqsut Pool: 92.13% Oooguruk-Kuparuk Pool: 5.54% Oooguruk-Torok Pool: 2.33% Theoretical production for individual wells for all pools is calculated on a daily basis. During 2014 wells were produced with chokes at 100% most of the time due to the capacity of the production line. Daily theoretical production for a well was calculated using the data from the most current well test and the amount of time a well was on production for a given day: Min Utes p, od«cea 1440 Minute clay xDailyRate(BOPD) «.erne,, = TheoreticalDaily Pr oduction The daily allocation factor for the unit is calculated by dividing the actual total production for the day by the sum of the theoretical daily production for each individual well. Daily allocated production is assigned to each well by multiplying its theoretical daily production by the daily allocation factor. The average daily allocation factor for 2014 was 1.0289. 5.0 Reservoir Management Summary The Alaska Oil and Gas Conservation Commission (AOGCC) issued pool rules under Conservation Orders No. 645, 596 and 597 for the Oooguruk-Torok, Oooguruk-Kuparuk Caelus Natural Resources Alaska, LLC Page 4 and Oooguruk-Nuiqsut reservoirs, respectively. Subsurface development of the Oooguruk Unit is done with dedicated development wells to the Oooguruk-Torok, Oooguruk-Nuiqsut and Oooguruk-Kuparuk oil pools with no subsurface commingling. Unitized substances produced from the Oooguruk-Torok, Oooguruk-Nuiqsut and the Oooguruk-Kuparuk oil pools are commingled on the surface. Area injection orders authorizing the injection of fluids for enhanced oil recovery in the Oooguruk-Kuparuk and Oooguruk-Nuiqsut reservoirs were issued by the AOGCC as Area Injection Orders No. 33 and 34, respectively. Pioneer Natural Resources Alaska, Inc., predecessor to Caelus, commenced injection into both reservoirs in 2009. At the end of 2014, there were three active producing and two active injecting Kuparuk wells. Kuparuk production rates have exceeded expectations due to non -matrix flow. Kuparuk injection commenced in 2009, into ODSK-38i with excellent injection rates. Kuparuk injection commenced in 2011 into ODSK-35Ai and ODSN-40 (converted from Nuiqsut completion to Kuparuk completion). Injection rate into ODSK-35i is very good, likely due open fracture networks within the reservoir section; however, injection into ODSN-40 was not sustainable due to very thin reservoir thickness at the location and lack of fractures. Water injection has arrested the gas/oil ratio (GOR) increase in the OKOP and has stabilized the flowing bottomhole pressures. The ODSK-33 experienced water breakthrough in August 2010. This was approximately the timing that reservoir simulation had suggested for breakthrough. The water cut increased relatively rapidly and reached approximately 95%+ by mid -year 2013 and the well was subsequently shut-in due to hydraulic backout at the Oooguruk drillsite (ODS). A three day test ending February, 2014 produced 12,733 bbis of water and two barrels of oil. ODSK-41 is much further away from injection and has seen a slower, effective response to water injection. A workover was completed on ODSK-41 in 2014 to replace the ESP. Injection was initiated in ODSK-42Ai in January 2010. Water broke through to offset producer ODSK-41 in less than 30 days immediately increasing the water cut to over 70% despite being over 2,700 ft away. In April 2010 a gel squeeze was performed successfully shutting off the fracture networks; unfortunately, in this thin area of the Kuparuk, 5 to 20 ft, it also appears there is very limited matrix permeability around the ODSK-42A wellbore as injection could not be sustained in the well, despite subsequent attempts to inject after a coil cleanout, re -perforating and a high pressure breakdown. ODSK-42Ai was shut-in during all of 2014 and is not functional in its current location. The Kuparuk in this eastern area of this fault block is very thin, but demonstrates good recovery from the ODSK-33 and ODSK-41 wells. The ODSK-42A surface slot and surface casing are in a very good position to efficiently drill, fracture and test the Nuiqsut in an untested area of the eastern Kalubik fault block, near well control (both ODSK-42 and ODSK-42A were drilled through the Nuiqsut). ODSK-35 and ODSK-14 were both drilled during 2010. The total thickness of the Kuparuk was less than expected in these wells to the north and northwest of the ODSK- Caelus Natural Resources Alaska, LLC Page 5 33. The wells had very high initial productivity from good reservoir quality, but declined rapidly due to the thinner nature of the reservoir in this area. ODSK-35Ai was converted to injection in late 2011 and a workover to replace the ESP in ODSK-14 was conducted in June 2013. With ODSK-35Ai and ODSK-33i both injecting, reservoir voidage replacement has been maintained, pressure in the reservoir is increasing and producing GORs have decreased. ODSK-13 was drilled in late 2011 as horizontal producer to test the thickness and productivity of the Ivik fault block. A workover was performed in 2013 to repair a failed SSSV. Production testing showed less than economic production rates and the well was converted to injection for short term testing in 2013 and 2014. The well is now shut-in for long term pressure monitoring. Pressures from the ODSK-13 injection and fall off test indicate the Ivik block is not in hydraulic communication with the main Kalubik block development area. Analyses of ODSK-13 oil samples show the asphaltene content is significantly higher than the Kalubik producing wells, which may explain the low productivity from the well. Integration of the ODSK-13 performance data with recent data collected while drilling to the Nuiqsut in this area is ongoing. ODSN-40, originally a Nuiqsut horizontal completion, had rig workover in 2011 to convert it to a dedicated Kuparuk injector. This well was completed and injected into the Kuparuk formation within the Colville -Delta fault block in 2012 in an attempt to aid with pressure support and oil recovery into the ODSK-33 producer within the Kalubik fault block. The well is currently shut-in due to low injectivity. Caelus Natural Resources Alaska, LLC Page 6 r N LL V Q� E U Poow !Y9 tlt Gti �.7 u�ry O rl aha. rymy p} tlJ �-i CG N Z N. . N N N O U `vi m ��' �=7 u1 tt7 u7 ttl ll 1 1f7 N U? L? p N C O tT w 0 Ol m N14 h h Ori C5 C � Q C E V oCm cc in co h 06 61oro a,tl1al O O N N rC V � m M C75 �^lry(� 6J � C'.7 0�9 YS^d d�J ry�ry V`i O CL Lry ai lC5 lt] lc lz lx r�i N a�-1 l�Cl pM 14 .P`1! NM 1-1 1-1 eP-'1I 14 M -I 1.4 rf q 14 M S m 14 uMuy tM�,ryry tM� uMry vM M O o0 O a) u .-I rl ri .-1 .-i ami .�-I N N N m N �o v a o A C A q Oco ro N t4 st1 Qj N N i' c 2 N N O 'LL .0-1 v0 -I rh-I .�-I e^ -I ri N V C 7 01 m d V) tD �o N co N N Ci u4''i � LO M M N try N N 4. VS U'' W n tU Qj 2 U C_ L N J U. O N O C? 2 E _. m N N N1-4 h m U m L N E V oCm cc in co h 06 61oro a,tl1al O O N N m h O h } r�i N a�-1 l�Cl pM 61 a v My m m �o v a o Qj 0-1 N N O 'LL .0-1 v0 -I rh-I .�-I e^ -I ri N V 7 vi 4. U'' W n Qj 2 L U. O N _. m N N N1-4 h m m L N N N N N ccc0 U1 N :s H .�-1 3 *'1 � .�-1 3 � .3i C i e�-1 a�-1 N OLLJ Q U N ATTACHMENT B: Map of Kuparuk Well Locations XA389956 ADL389 5'5 G�G6r ���...,, .4.. ADL379301 oADL . 60 ADL389959 F ADL389 58` i ODSK-13 ADL389954 ADL389 53 O � OD O S 35 l�-14 ° D 7 3899 ! ADL3 949 ADL355037 A L3 6 j K- A`pL3$9 52 ADL38 51 OD I / VT Legend Kuparuk Pool ADL355039 Kuparuk PA ADL3 038 N Unit Boundary w+E Lease Boundary S Township Boundary e --- Miles 0 0. 1 3 4 a E E 11O, UL �5 E ® o o n r a Q m 3 g 1 n o N R �' r3 a Q fV IV N Fi fV N N ry0. N � Q�} aQ yy LC 3' O O O O O O O O O G �+ yya O W O` ry a ppp N_ 8 Q ri CJ W tV Rr O TA � a gg ai v d e OW/ n n z o = O W a a�N =_ cn W LL W ^ Z ,� HOU CL ^ O `o LL! 8 N P1 � ^ lG t0 1011 N t0 �D LLO1 lf� � t0 YY W C N d �2$ a v ti n �° ti ti n R n Cb a if1 iA N IA iL1 N N N N N O c 2 3 O o O 3 3 0 3 3 3 3 o g 8 c � mgt q $$3 o o IR o o J z @@" gm j y� Z Ny Y Y Y Y Y YY s� 6 8 O O § § § O py ATTACHMENT D: Kuparuk Reservoir Pressure Map — 2014 C CAELUS Energy Alaska Annual Reservoir Surveillance Report Oooguruk-Torok Oil Pool Oooguruk Field April 1, 2015 Table of Contents SUBJECT PAGE 1.0 Progress of the Enhanced Recovery Project................................................................ 3 2.0 Results and Analysis of Reservoir Pressure Surveys within the Pool ....................... 4 3.0 Results and Analysis of Production and Injection Log Surveys, Tracer Surveys, Observation Well Surveys and Any Other Special Monitoring ................................... 4 4.0 Review of Pool Production Allocation Factors and Issues Over the Year .................. 4 5.0 Reservoir Management Summary. ATTACHMENTS......... ........................................................................ 5 ............................. Error! Bookmark not defined. ATTACHMENT A: Voidage Balance by Month of Produced Fluids and Injected Fluids 2014 6 ATTACHMENT B: Map of Torok Well Locations................................................................... 7 ATTACHMENT C: Nuna Torok Phase 1 Map View................................................................ 8 ATTACHMENT D: Form 10-412 Pressure Report for Torok ................................................... 9 ATTACHMENT E: Torok Reservoir Pressure Map — 2014 ....................................................10 ATTACHMENT F: ODST-46 Pressure Monitoring and Daily Injection Volumes ....................11 1.0 Progress of the Enhanced Recovery Project During 2014 Oooguruk-Torok Oil Pool (OTOP) development progressed as planned. In 2012 the Alaska Oil and Gas Conservation Commission (AOGCC) issued Area Injection Order 37 (AIO 37) authorizing injection of fluids into the OTOP for the purposes of pressure maintenance and enhanced oil recovery. Injection operations were initiated on December 5, 2012 in ODST-46 and continued through 2014. Production continues from horizontal fracture stimulated producers ODST-45A and ODST-39. However, ODST- 45A has been shut-in since June, 2014 due to a failed electronic submersible pump (ESP), March, 2014, and a failed packer vent valve, June, 2014, preventing use of gas to lift the well. A workover to repair the completion is scheduled in 2015. A fourth Oooguruk drillsite (ODS) development well, ODST-47, was drilled and completed in 2012 and hydraulically fracture stimulated during the 2013 winter season. Unfortunately, the lower completion in the well failed during the final stages of the stimulation treatment preventing production from the lateral; remedial alternatives are under evaluation. The locations of the existing OTOP wells are shown on Attachment B. An integrated project assessment of the Nuna Torok Phase 1 Development was completed in 2014. The scope for the Nuna Torok Phase 1 Development includes a new Nuna drillsite (NDS1), a road to KRU drillsite 3S, expansion of the Oooguruk Tie-in Pad (OTP) infrastructure, and 31 wells consisting of 14 new injectors, 14 new producers, two existing wells, Nuna 1 and NDST-2, and one Class 1 non -hazardous waste disposal well. NDS1 will be five miles south of the existing ODS. Attachment C depicts the existing Torok wells as well as the Nuna Torok Phase 1 Development wells to be drilled from NDS1. 2014 Oooguruk Unit (OU) seawater injection was interrupted by Kuparuk River Unit (KRU) seawater flowline corrosion repairs. OU receives seawater from the KRU Seawater Treatment Plant (STP) via the KRU Central Production Facility 3 (CPF3). The KRU 10 in. flowline from CPF3 to OU was shut in for corrosion anomalies on March 24, 2014. KRU implemented a temporary seawater flowline route allowing OU to re- establish injection on September 10, 2014. OU was without seawater injection supply for this 170 -day period. Seawater injection continued in ODST-46 and the well was monitored pursuant to the rules of AIO 37. The well demonstrated mechanical integrity while on seawater injection, but showed tubing to inner annulus communication while on gas injection; additionally, the ODSN-48 wellbore was drilled within 1,000 ft of ODST-46 and required remedial cementing operations in the intermediate casing string. Consequently the ODST-46 well will not be placed in gas injection service. Attachment F, in compliance with AIO 37, Rule 9, details the well injection pressures and injection for the report period. Annual average daily Torok production for 2014 was 264 BOPD. Cumulative oil production from the OTOP during 2014 was 96 MBO and is 785 MBO since field start- up through 2014. Caelus Natural Resources Alaska, LLC Page 3 Torok water injection was limited to 18 days in 2014 due to water supply interruptions and drilling close approaches for wells ODSN-48 and ODSN-43. Daily average Torok water injection in 2014 was 848 BWPD. Cumulative water injection in the OTOP during 2014 was 15 thousand BW and 573 thousand BW since the start of the project. In 2014 no gas was injected in the OTOP. Cumulative gas injection in the OTOP is 171 Mscf since the start of the project. Attachment A details the 2014 monthly voidage for the OTOP. 2.0 Results and Analysis of Reservoir Pressure Surveys within the Pool Six pressure surveys were conducted in four OTOP wells during 2014. The extended pressure build ups in both ODST-45A and ODST-39, coupled with the ODST-46i falloff data suggest similar levels of depletion and continuity in this initial development area. The pressure measured in ODST-47 is consistent with the OTOP original reservoir pressure. While drilling and casing the intermediate sections in both ODSN-48 and ODSN-43, both of which were within 1,000 feet of ODST-46i at the Torok level, there was no evidence of fracturing through or migration above the confining interval. Attachment C and D detail the surveys and relevant data. 3.0 Results and Analysis of Production and Injection Log Surveys, Tracer Surveys, Observation Well Surveys and Any Other Special Monitoring Resman surveillance equipment was placed in the production liner of ODST-47 to assess oil and water production conformance along the lateral via target fluid tracers; results are pending production from the well. 4.0 Review of Pool Production Allocation Factors and Issues Over the Year Production from the Oooguruk-Nuiqsut, Oooguruk-Kuparuk and Oooguruk-Torok pools is commingled at the surface into a common production line. Allocation between the pools is based on ratio of total production for a pool to the total production for the Oooguruk Unit. The pool allocation factors for 2014 are: Oooguruk-Nuiqsut Pool: 92.13% Oooguruk-Kuparuk Pool: 5.54% Oooguruk-Torok Pool: 2.33% Theoretical production for individual wells for all pools is calculated on a daily basis. During 2014 wells were produced with chokes at 100% most of the time due to the capacity of the production line. Daily theoretical production for a well was calculated using the data from the most current well test and the amount of time a well was on production for a given day: Caelus Natural Resources Alaska, LLC Page 4 Minutesproduced xDailyRate(BOPD).er��P51=Theor-eticalDailyProduetion 1440 Minutes day The daily allocation factor for the unit is calculated by dividing the actual total production for the day by the sum of the theoretical daily production for each individual well. Daily allocated production is assigned to each well by multiplying its theoretical daily production by the daily allocation factor. The average daily allocation factor for 2014 was 1.0289. 5.0 Reservoir Management Summary The AOGCC issued pool rules under Conservation Orders No. 645, 596 and 597 for the Oooguruk-Torok, Oooguruk-Kuparuk and Oooguruk-Nuiqsut reservoirs, respectively. While there is no subsurface commingling, unitized substances produced from the three oil pools are commingled on the surface. At the end of 2014, there were two active producing Torok wells and one Torok injection well. An additional producer, ODST-47 is awaiting remedial work. Injection in ODST-46 has seen no adverse effects (i.e. early breakthrough or limited injectivity). OTOP development of the Nuna area continued with completion of a multi -discipline, integrated project assessment of the commercial viability of the Nuna onshore OTOP development. The Nuna Torok Phase 1 Development, located on the North Slope of Alaska, will develop approximately 105 MMBO (gross) and yield peak production in excess of 20,000 BOPD in 2020. Wells within the Nuna Torok Phase 1 Development will range from 11,200 ft MD to 20,500 ft MD with an average lateral length of 5,300 ft. These producer/injector wells are nominally 6,000 ft horizontal completions in the Torok formation on Caelus' leases in a pattern similar to ODS development. The field will obtain secondary recovery via line drive water injection with alternating producer - injector pairs oriented northwest -southeast, consistent with the field's maximum stress direction. To overcome very limited vertical permeability and low horizontal permeability both the injectors and the producers will be completed using leading edge completion technology, developed by Caelus, including multi -stage mechanically diverted, single sleeve hydraulic fracture stimulations. The current lower completion design includes approximately two million pounds of proppant evenly placed in 12 distinct stages along the lateral of well pumping at 40 to 50 barrels per minute. The focused hydraulic fracture stimulations maximize reservoir contact vertically and propagate longitudinally relative to the wellbore enhancing both well rates and reserves. Caelus Natural Resources Alaska, LLC Page 5 r r Q N N LL Q 4w V C .O C c3 N LL V O L a. 4- 0 s c O 5 O V M� W O N �' m lA u'f �p1 e -I cM} !t d7 t816 (75 cS0 Q C3h+ N n a C C ,�.+ C` N w"7 �&7 ld t�0 tPG t�G fes+ h h O_ rJES ,� ri ri ri ri .ti ri .i ri ri ,-i rl ri fi N N N N f*1 N N N N N N m L m p ti 'Ci b C CJ o N c 0 n � O FC, 0i N Oco c y LL CU CO r U a b N c h h f`W fw n n n n n A SC � N' CV N N N N f*1 N N N N N N m L m ti 'Ci b � o N c 0 n � FC, 0i N c y LL CU CO r U — 1: m um a a o o o 0 0 o a a o 0 0 m N t0 A t; cu v u, oN V C L e�-I .�-1 -I Q 4 N X19 a N N N w t'7 7 t v in SC � N' CV N N N N f*1 N N N N N N L m ti 'Ci b � N � LL CU CO U 7 N t0 A cu u, oN L e�-I .�-1 -I Q 4 N X19 a N N N w t'7 t LnLn C o in ro a m e no sj t>b F_ u� Sc Q Q n 6 z d u N ATTACHMENT B: Map of Torok Well Locations ADL389956 ADL389955 ADL379301 ADL389960 ADL389959 ADL389958 ADL389954 ADL389953 i ti ADL389950 ADL389949 ODST ADL35503 OD 3 T-39 ADL35 6 R S 5A ADL389952 ADL389951 a A %NDST-2 T-47 I r A[ L355039 ? a ADL355038 3 NU A-1 Legend N Torok Pool wE Q Current Torok PA S i Q Unit Boundary Lease Boundary 0 0.6 1 2 MIS@S 4 Q Township Boundary Proposed NDS1 Pad ATTACHMENT C: Nuna Torok Phase 1 Map View Oooguruk Uni'm Oooguruk Drills to {ODS} uhj 1 p r' !� t „ x - . "M A �'"r'� Existing development well Planned Phase 1 injector 0 2 4 Miles - I Planned Phase 1 producer Caelus Natural Resources Alaska, LLC Page 8 L P -0 L- 0 � D o � z w 2 U) U) F- CL «C-4 � 0 E 0 U- )� k ! ( # $ R 4° � \\ �f U ) § !!! \� i) CL / LU ! UJ ��*/2��� G0 ! f�! 22� - Lu \ ! \ CL !! § ) § § § ` ) (off ! \ � 2, Uj a ■ ! ; ; § ! | « f!f0 00 k t o ! ! |\ � \! ! ■ � !f / )wf § § § k § 0 ATTACHMENT E: Torok Reservoir Pressure Map — 2014 450000 48000 4NON 4600= 3t 3i 33 34 T14NR 3' -� 31 T14NR8E 32 33 3 z , 6 s a F I p 6030000 DST -0 ] e 92¢ giDST-39,? 1, 12 ] a s 13 7 1B 17 15 m 13 16 17 16 T131VR7E 4 t .. T13N)P, E t Legend 6020000 19 20 21 24 19 r Torok Pool 20000 r O T-4 Q Torok PA 2237 Torok Pressure PSI 30 29 ! 25 27 % 25 30 1.385- 1,400 1,400- 1,500 1 1,500- 1,600 1,600- 1,700 1,700- 1,800 0010000 — 31 32 35 34 35 36 1 31 1,800- 1,900 10000 1,900 - 2;000 i 2,000 - 2.100 w .�..,.,....,.-»,.._x 2,100 - 2.200 /r t 2.200 - 2,300 ° 3 2 1 6 5 2,300 - 2,400 J T12NR7E T12NR8 _ 2.400 - 2,500 2,500 - 2,600 �� 0 0.5 1 2 Miles 11 12 7 a 2,600 - 2,700 00000 450000 460000 470000 460000 ATTACHMENT F: ODST-46 Pressure Monitoring and Daily Injection Volumes (AIO 37, Rule 9) Caelus Natural Resources Alaska, LLC Page 11 Inj Pressure IA Pressure OA Pressure GAS ]NJ (mscfd) WATER ]NJ (bbI/dj 2014 PI_27210C PI_27210G P1_27210H AVM FI 23210 AVM FI 342113 MONTH DAY MIN MAX AVERAGE MIN MAX AVERAGE MIN MAX AVERAGE Daily Total Daily Total January 1 1,183 1,286 1,283 598 599 599 5 6 5 0 0 January 2 1,273 1,279 1,276 599 600 599 5 5 5 0 0 January 3 1,273 1,277 1,276 598 599 598 4 5 4 0 0 January 4 1,271 1,275 1,273 599 602 600 4 5 5 0 0 January 5 1,268 1,273 1,271 602 603 603 5 5 5 0 0 January 6 1,263 1,268 1,266 603 605 604 5 5 5 0 0 January 7 1,260 1,266 1,262 1 605 608 606 5 6 1 5 0 0 January 8 1,258 1,262 1,260 608 611 609 5 6 6 0 0 January 9 1,258 1,261 1,260 610 612 611 5 6 6 0 0 January 10 1,253 1,260 1,257 612 620 615 5 6 6 0 1 0 January 11 1,251 1,258 1,256 620 636 627 6 6 6 0 0 January 12 1,247 1,251 1,250 636 657 647 6 6 6 0 0 January 13 1,240 1,247 1,243 1 657 670 663 6 6 6 0 0 January 14 1,234 1 1,241 1,237 670 686 678 6 6 1 6 0 0 January 15 1,229 1,234 1,231 686 703 694 6 6 6 0 0 January 16 1,221 1,229 1,226 703 725 713 6 6 6 0 0 January 17 1,214 1,222 1,218 725 753 739 6 7 6 0 0 January 1 18 1,213 1 1,217 1,215 1 753 776 765 6 7 7 0 0 January 19 1,209 1,214 1,212 777 804 791 7 1 8 1 8 0 0 January 20 1,204 1,209 1,207 804 827 815 8 8 8 0 0 January 21 1,203 1,205 1,204 827 851 839 8 8 8 0 0 January 22 1,201 1,203 1,202 851 873 863 8 8 8 0 1 0 January 23 1,199 1,202 1,200 873 890 882 8 8 8 0 0 January 24 1,196 1,200 1,198 890 906 898 8 1 8 1 8 0 0 January 25 1,196 1,197 1,196 906 922 914 8 9 8 0 0 January 26 1 1,195 1,197 1 1,195 922 939 931 9 9 9 0 0 January 27 1,193 1,195 1,194 939 949 944 9 9 9 0 0 January 28 1,191 1,194 1,192 949 959 954 9 9 9 0 0 January 29 1,188 1,191 1,189 959 969 964 9 1 9 1 9 0 0 January 30 1,185 1,188 1,187 969 978 974 9 9 9 0 0 January 31 1,183 1,186 1,184 978 985 982 9 9 9 0 0 February 1 1 1,180 1,183 1 1,182 985 1 992 989 9 9 9 0 0 Caelus Natural Resources Alaska, LLC Page 11 February 1 2 1,176 1 1,180 1,179 1 992 996 994 9 9 9 0 0 February 3 1,171 1,176 1,174 996 999 998 9 9 9 0 0 February 4 1,167 1,172 1,169 999 1,000 999 9 9 9 0 0 February 5 1,162 1,168 1,165 999 1,000 1,000 9 9 9 0 0 February 6 1,158 1,163 1,160 999 1,000 1,000 9 9 9 0 0 February 7 1,154 1,159 1,157 999 1,000 1,000 9 9 9 0 0 February 8 1,151 1,155 1,152 999 1,000 999 9 9 9 0 0 February 9 1 1,146 1,151 1,149 999 1 1,000 999 9 9 9 0 0 February 10 1,143 1,147 1,145 999 1,000 999 9 9 9 0 0 February 11 1,140 1,143 1,141 998 999 999 8 9 8 0 0 February 12 1,136 1,140 1,138 998 998 998 7 8 7 0 0 February 13 1,135 1,137 1,135 997 998 997 7 7 7 0 0 February 14 1 1,132 1,135 1,133 997 997 997 7 7 7 0 0 February 15 1,128 1,133 1,131 997 998 997 7 7 7 0 0 February 16 1,126 1,129 1,128 997 998 997 7 7 7 0 0 February 17 1,123 1,126 1,125 997 998 997 7 7 7 0 0 February 18 1,121 1,124 1,122 997 997 997 7 7 1 7 0 0 February 19 1 1,118 1,121 1,120 997 998 997 7 7 7 0 0 February 20 1,116 1,119 1,118 997 998 997 7 7 7 0 0 February 21 1,113 1,117 1,115 997 998 997 7 7 7 0 0 February 22 1,110 1,114 1 1,112 997 998 997 7 7 7 0 0 February 23 1,109 1,111 1 1,110 996 997 996 7 7 7 0 0 February 24 1,107 1,110 1,109 997 997 997 7 8 7 0 0 February 25 1,106 1,108 1,107 997 998 997 7 8 8 0 0 February 26 1,103 1,107 1,105 996 997 997 8 8 8 0 0 February 27 1,102 1,105 1,103 994 996 995 7 8 7 0 0 February 28 1,099 1,102 1,100 994 996 995 7 8 8 0 0 March 1 1,096 1,100 1,098 996 996 996 8 9 8 0 0 March 1 2 1,095 1,097 1,096 994 996 995 8 8 8 0 0 March 3 1,093 1,095 1,094 994 994 994 8 8 8 0 0 March 4 1,091 1,094 1,092 992 994 993 8 8 8 0 0 March 5 1,088 1,092 1,090 990 992 992 8 8 8 0 1 0 March 6 1,085 1,089 1,087 983 990 1 986 8 1 8 8 0 0 March 7 1,084 1,973 1,794 845 1,069 897 8 146 1 94 0 1245 March 8 1,888 1,957 1,935 888 913 899 146 172 159 0 1,200 March 9 1,943 2,009 1,978 899 927 915 158 182 172 0 1,047 March 10 2,009 2,061 2,039 1 858 919 898 126 174 158 0 1,016 March it 2,061 2,093 2,079 880 921 904 140 175 160 0 987 March 12 2,059 2,107 2,077 908 935 919 160 1 184 1 170 0 919 March 13 2,107 2,121 2,115 899 936 913 1551 166 0 919 March 14 2,098 2,133 1 2,125 899 906 902 156 -Ind 1 162 1 158 0 900 Caelus Natural Resources Alaska, LLC Page 12 March 15 2,089 2,135 2,104 1 906 917 912 161 170 167 0 843 March 16 2,134 2,149 2,143 892 915 899 151 170 157 0 861 March 17 2,148 2,157 2,153 891 937 913 151 192 170 0 850 March 18 2,118 2,158 2,135 915 934 926 170 188 180 0 817 March 19 2,146 2,176 2,167 908 935 920 164 188 175 0 829 March 20 2,172 2,178 2,176 903 913 908 160 169 165 0 829 March 21 1,954 2,177 2,121 907 920 913 161 174 167 0 755 March 22 1,312 2,135 2,033 863 922 903 110 1 163 145 0 659 March 23 1,301 2,143 21031 906 1,156 1,080 136 363 298 0 591 March 24 1,189 2,224 1,293 1,090 1 1,257 1,190 -1 255 75 0 0 March 25 50 1,189 1,131 1,257 1,289 1,276 -4 -1 -3 0 0 March 26 45 66 48 1,258 1,284 1,269 -3 -1 -2 0 0 March 27 45 46 46 1,239 1,258 1,249 -1 0 -1 0 0 March 28 45 46 45 1,222 1,239 1,230 0 0 0 0 0 March 29 45 47 46 1,213 1 1,222 1,216 0 1 0 0 0 March 30 40 47 43 1,214 1,217 1,216 0 1 0 0 0 March 31 39 40 40 1,217 1,220 1,218 0 1 0 0 0 April 1 39 40 40 1,219 1,222 1,221 1 1 1 0 0 April 2 38 40 39 1,222 1,223 1,223 1 1 1 0 0 April 3 37 38 38 1,223 1,224 1,223 1 1 1 0 0 April 4 37 39 38 1,224 1,225 1,224 1 2 2 0 0 April 5 36 39 38 1,225 1,225 1,225 2 2 2 0 0 April 6 35 36 35 1,224 1,225 1,225 2 2 2 0 0 April 7 35 37 36 1,225 1,226 1,225 2 3 2 0 0 April 8 36 37 37 1,226 1,226 1,226 3 3 3 0 0 April 9 34 37 35 1,225 1,226 1,226 3 3 3 0 0 April 10 36 37 37 1,226 1,227 1,226 3 3 3 0 0 April 11 34 37 35 1,226 1,227 1,226 3 3 3 0 0 April 12 35 38 37 1,226 1,227 1,226 3 4 4 0 0 April 13 38 1,444 1 1,406 1,227 1,227 1,227 4 4 4 0 0 April 14 1,422 1,458 1,443 1,226 1,227 1,227 4 5 4 0 0 April 15 1,417 1,447 1,433 1,226 1 1,227 1,226 5 5 5 0 0 April 16 1,433 1,467 1,457 1,226 1,226 1,226 5 5 5 0 0 April 17 1,428 1,456 1,443 1,225 1,226 1,225 5 5 5 0 0 April 18 1 1 1,433 1 918 1,224 1,225 1,224 5 5 5 0 0 April 19 0 1 1 1,223 1,224 1,224 5 5 5 0 5 April 20 0 1 1 1,223 1,224 1,223 5 5 5 0 0 April 21 0 1 0 1,222 1,223 1,222 5 5 5 0 0 April 22 0 49 19 1,222 1,222 1,222 5 6 5 0 0 April 23 1 49 1 1,571 1 1,363 1,221 1,222 1,222 5 6 6 0 0 April 24 1,517 1,579 1 1,558 1,221 1,224 1,222 6 6 6 0 0 Caelus Natural Resources Alaska, LLC Page 13 April 25 1,518 1 1,587 1,557 1 1,220 1,223 1,221 6 6 6 0 0 April 26 1,500 1,545 1,525 1,220 1,220 1,220 6 6 6 0 0 April 27 1,428 1,540 1,496 1,219 1,220 1,219 6 6 6 0 0 April 28 1,370 1,428 1,391 1,217 1,219 1,218 5 6 5 0 0 April 29 1,361 1,548 1,412 1,217 1,217 1,217 5 6 5 0 0 April 30 1 1,548 1,591 1 1,579 1,217 1 1,218 1,217 6 1 6 6 0 0 May 1 1,591 1,652 1,641 1,217 1,218 1,218 6 7 6 0 0 May 2 1,646 1,660 1,654 1,217 1,218 1,217 7 7 7 0 0 May 3 1,601 1,646 1,618 1,216 1,217 1,217 6 7 7 0 0 May 4 1,610 1,637 1,622 1,216 1,216 1,216 7 7 7 0 0 May 5 1 1,614 1,633 1,625 1,215 1,216 1,215 7 7 7 0 0 May 6 1,577 1,624 1,602 1,214 1,215 1,215 7 7 7 0 0 May 7 1,601 1,643 1,630 1,214 1,214 1,214 7 7 7 0 0 May 8 1,611 1,646 1,631 1,213 1,214 1,214 7 7 7 0 0 May 9 1,601 1,647 1,626 1,213 1,214 1,213 7 8 7 0 0 May 10 1,584 1,650 1,612 1,212 1,213 1,212 7 8 7 0 0 May 11 1,527 1,650 1,605 1,211 1,212 1,212 7 8 8 0 0 May 12 1,629 1,648 1,639 1,211 1,211 1,211 8 8 8 0 0 May 13 1,633 1,652 1,641 1,210 1,211 1,211 8 8 8 0 0 May 14 1,630 1,646 1,638 1,210 1,211 1,210 8 8 8 0 0 May 15 1,605 1,642 1,630 1,209 1,210 1,209 8 8 8 0 0 May 16 1,625 1,648 1,639 1,208 1,209 1,209 8 8 8 0 0 May 17 1,602 1,640 1,623 1,208 1,209 1,208 8 1 8 8 0 0 May 18 1,602 1,629 1,616 1,207 1,208 1,207 8 8 8 0 0 May 19 1,602 1,630 1,612 1,206 1,207 1,207 8 8 8 0 0 May 20 1,595 1,631 1,619 1,206 1,207 1,206 8 9 8 0 0 May 21 1,629 1,642 1,636 1,205 1,206 1,206 8 9 9 0 0 May 22 1,623 1,633 1,629 1,205 1,205 1,205 9 9 9 0 0 May 23 1,602 1,623 1,613 1,204 1,205 1,204 8 9 9 0 0 May 24 1,605 1,628 1,621 1,203 1,204 1,203 8 9 9 0 0 May 25 1,594 1,619 1,609 1,202 1,203 1,203 8 9 9 0 0 May 26 1,557 1,622 1,582 1,201 1,202 1,202 8 9 8 0 0 May 27 1,622 1,646 1,633 1,201 1,202 1,201 9 9 9 0 0 May 28 1 1,630 1,653 1 1,645 1,201 1 1,201 1,201 9 9 9 0 0 May 29 1,615 1,646 1,629 1,200 1,201 1,201 9 9 9 0 0 May 30 1,592 1,626 1,619 1,199 1,200 1,200 9 9 9 0 0 May 31 1,623 1,629 1,626 1,199 1,199 1,199 9 9 9 0 0 June 1 1,616 1,627 1,622 1,198 1,199 1,199 9 9 9 0 0 June 2 1 1,606 1 1,630 f 1,620 1,198 1 1,198 1,198 9 9 9 0 0 June 3 1,630 1,648 1,640 1,197 11198 1,198 9 9 9 0 0 June 4 1 1,626 1,639 1,634 1,196 1,197 1,197 9 9 9 0 0 Caelus Natural Resources Alaska, LLC Page 14 July 16 823 1 825 824 1 1,173 1,174 1 1,174 8 8 8 0 0 July 17 822 823 823 1,173 1,174 1,173 8 8 8 0 0 July 18 821 823 822 1,172 1,173 1,172 8 8 8 0 0 July 19 820 821 821 1,171 1,172 1,171 8 9 9 0 0 July 20 819 820 820 1,170 1,171 1,171 9 9 9 0 0 July 21 818 819 819 1,170 1,170 1,170 9 9 9 0 0 July 22 817 818 818 1,169 1,170 1,169 9 9 9 0 0 July 23 816 817 817 1,168 1,169 1,168 9 9 9 0 0 July 24 816 817 817 1,168 1,168 1,168 9 10 9 0 0 July 25 1 814 816 815 1,167 1,168 1,167 9 10 9 0 0 July 26 813 815 814 1,166 1,167 1,167 9 10 9 0 0 July 27 811 813 812 1,165 1,166 1,166 9 10 9 0 0 July 28 810 812 811 1,165 1,166 1,165 10 10 10 0 0 July 29 810 811 810 1,165 1,166 1,165 10 10 10 0 0 July 30 809 810 809 1,165 1,165 1,165 10 10 10 0 0 July 31 807 809 808 1,164 1,165 1,164 10 10 10 0 0 August 1 807 808 807 1,164 1,165 1,165 10 11 11 0 0 August 2 806 807 806 1,164 1,165 1,164 10 11 10 0 0 August 3 805 806 806 1,164 1,164 1,164 10 10 10 0 0 August 4 803 1 805 804 1,163 1,164 1,164 10 10 10 0 0 August 5 802 804 803 1,163 1,164 1,163 10 11 10 0 0 August 6 802 803 802 1,163 1,164 1,164 11 11 11 0 0 August 7 800 802 801 1,164 1,164 1,164 11 11 11 0 0 August 8 799 801 800 1,163 1,164 1,164 11 11 11 0 0 August 9 798 799 799 1,163 1,164 1,164 11 11 11 0 0 August 10 797 799 798 1,163 1,164 1,163 11 11 11 0 0 August 11 796 798 797 1,163 1,163 1,163 11 12 11 0 0 August 12 795 797 796 1,163 1,164 1,163 12 12 12 0 0 August 13 794 796 795 1,163 1,164 1,163 12 12 12 0 0 August 14 794 795 794 1,163 1,163 1,163 12 12 12 0 0 August 15 793 794 793 1,163 1,163 1,163 12 12 12 0 0 August 16 792 1 793 792 1 1,163 1,163 1,163 12 12 12 0 0 August 17 791 792 791 1,163 1,164 1,163 12 12 12 0 0 August 18 790 791 790 1,163 1,164 1,164 12 13 13 0 0 August 19 789 790 789 1,163 1,164 1,164 13 13 13 0 0 August 20 788 789 789 1,163 1,164 1,164 13 13 13 0 0 August 21 786 1 788 787 1 1,163 1,164 1,164 13 13 13 0 0 August 22 786 787 786 1,164 1,164 1,164 13 14 13 0 0 August 23 790 791 786 1,163 1,164 1,163 12 13 17 0 0 August 24 784 785 784 1,164 1,164 1,164 14 14 14 0 0 August 25 783 784 783 1,163 1 1,164 1,164 13 14 14 0 0 Caelus Natural Resources Alaska, LLC Page 16 August 26 782 1 783 783 1 1,163 1,164 1 1,164 13 14 14 0 0 August 27 781 783 782 1,163 1,164 1,164 14 14 14 0 0 August 28 758 784 778 1,164 1,164 1,164 14 14 14 0 0 August 29 768 781 775 1,164 1,164 1,164 14 14 14 0 0 August 30 774 785 781 1,163 1,164 1,164 14 14 14 0 0 August 31 750 776 767 1,163 1,164 1,164 13 14 13 0 0 September 1 1 737 1 750 742 1,163 1,163 1,163 13 13 13 0 0 September 2 1 734 737 736 1,163 1,163 1 1,163 13 13 13 0 0 September 3 732 743 736 1,163 1,163 1,163 12 13 13 0 0 September 4 731 738 736 1,163 1,163 1,163 12 13 12 0 0 September 5 727 731 728 1,163 1,163 1,163 12 13 13 0 0 September 6 724 729 727 1,163 1,163 1,163 12 13 13 0 0 September 7 717 734 725 1,163 1,163 1,163 12 13 13 0 0 September 8 731 738 733 1,163 1,163 1,163 13 13 13 0 0 September 9 732 734 733 1,163 1,163 1,163 12 13 12 0 0 September 10 731 733 732 1,163 1,163 1,163 12 1 12 12 0 0 September 11 732 734 733 1,163 1,163 1,163 11 12 12 0 0 September 12 730 735 733 1,163 1,163 1,163 11 12 11 0 0 September 13 726 731 728 1,162 1,163 1,163 11 11 11 0 0 September 14 725 1 728 727 1,162 1,163 1,163 11 11 11 0 0 September 15 724 729 727 1,162 1,163 1,163 11 12 12 0 0 September 16 727 730 729 1,162 1,163 1,163 12 12 12 0 0 September 17 727 739 731 1,163 1 1,163 1,163 12 12 12 0 0 September 18 730 737 733 1,162 1,163 1,163 12 12 12 0 0 September 19 736 742 740 1,162 1,163 1,162 12 12 12 0 0 September 20 716 742 737 1,162 1,163 1,162 12 12 12 0 0 September 21 698 730 718 1,162 1,162 1,162 it 12 12 0 0 September 22 718 729 722 1 1,162 1,162 1 1,162 10 11 11 0 0 September 23 719 732 725 1,162 1,162 1,162 9 11 10 0 0 September 24 685 725 714 1,161 1,162 1,162 6 10 8 0 0 September 25 660 705 673 1,161 1,162 1,161 3 6 4 0 0 September 26 705 777 761 1,161 1,162 1,161 3 3 3 0 0 September 27 755 769 763 1 1,161 1,162 1 1,162 3 1 3 3 0 0 September 28 754 758 756 1,161 1,162 1,161 2 3 3 0 0 September 29 757 764 761 1,161 1,162 1,162 2 2 2 0 0 September 30 758 764 761 1,161 1,162 1,162 2 2 2 0 0 October 1 755 761 1 758 1,161 1,162 1,162 2 2 2 0 0 October 2 753 760 756 1,150 1,178 1,162 2 1 3 2 0 0 October 3 749 763 753 1,161 1,162 1,161 2 3 2 0 0 October 4 763 771 769 1,161 1,161 1,161 2 2 2 0 0 October 5 769 772 771 1,160 1,161 1,161 2 3 2 0 0 Caelus Natural Resources Alaska, LLC Page 17 October 6 753 1 773 768 1 1,160 1,161 1 1,160 2 3 2 0 0 October 7 759 774 768 1,160 1,160 1,160 2 3 3 0 0 October 8 771 779 775 1,160 1,160 1,160 3 3 3 0 0 October 9 771 777 773 1,160 1,160 1,160 2 3 3 0 0 October 10 770 776 773 1,159 1,160 1,159 2 2 2 0 0 October 11 1 770 774 1 772 1,159 1 1,159 1,159 2 2 2 0 0 October 12 770 772 772 1,159 1,159 1,159 2 2 2 0 0 October 13 770 772 771 1,159 1,159 1,159 2 3 2 0 0 October 14 767 771 770 1,158 1,159 1,159 2 3 2 0 0 October 15 767 773 770 1,158 1,159 1,158 2 2 2 0 0 October 16 767 772 1 770 1,158 1,158 1,158 2 2 2 0 0 October 17 764 773 768 1,158 1,158 1,158 2 2 2 0 0 October 18 762 766 764 1,158 1,158 1,158 2 2 2 0 0 October 19 736 765 752 1,157 1,158 1,158 2 2 2 0 0 October 20 729 741 736 1,157 1,157 1,157 1 2 2 0 0 October 21 729 746 736 11157 1,157 1,157 1 2 2 0 0 October 22 732 758 745 1,157 1,157 1,157 2 2 2 0 0 October 23 757 765 761 1,157 1,157 1,157 2 3 2 0 0 October 24 758 765 761 1,157 1,157 1,157 2 3 2 0 0 October 25 7S6 760 758 1,157 1,157 1,157 2 2 2 0 0 October 26 756 769 765 1,156 1,157 1,157 2 3 2 0 0 October 27 758 764 760 1,156 1,157 1,157 2 2 2 0 0 October 28 757 769 760 1,156 1,157 1,157 2 2 2 0 0 October 29 758 773 765 1,156 1,157 1,157 2 3 2 0 0 October 30 759 1 769 765 1,156 1,157 1,157 2 3 2 0 0 October 31 757 766 760 1,156 1 1,157 1,156 2 3 2 0 0 November 1 748 759 755 1,156 1,156 1,156 2 2 2 0 0 November 2 736 749 743 1,155 1,156 1,156 2 2 2 0 0 November 3 729 742 733 1,155 1,155 1,155 2 1 2 2 0 0 November 4 742 749 748 1,155 1,156 1,156 2 2 2 0 0 November 5 730 748 744 1,155 1 1,156 1,156 2 2 2 0 0 November 6 712 745 730 1,155 1,155 1,155 1 2 2 0 0 November 7 744 749 747 1,155 1,155 1,155 2 2 2 0 0 November 8 746 749 747 1,155 1,155 1,155 2 2 2 0 0 November 9 747 755 752 1,155 1,155 1,155 2 3 2 0 0 November 10 749 764 755 1,155 1 1,155 1,155 2 3 3 0 0 November 11 746 763 752 1,154 1,155 1,155 2 3 3 0 0 November 12 750 765 756 1,154 1,155 1,155 2 3 3 0 0 November 13 748 767 760 1,154 1,155 1,155 3 3 3 0 0 November 14 746 754 750 1,154 1,155 1,154 2 3 3 0 0 November 15 748 762 757 1 1,154 1 1,154 1 1,154 2 3 3 0 0 Caelus Natural Resources Alaska, LLC Page 18 November 1 16 753 762 759 1 1,154 1,154 1 1,154 3 3 3 0 0 November 17 1 755 391 1,153 1,154 1,154 2 3 2 0 0 November 18 5 6 6 1,153 1,154 1,153 2 2 2 0 0 November 19 5 6 6 1,153 1,153 1,153 2 2 2 0 0 November 20 5 6 6 1,152 1,153 1,153 2 2 2 0 0 November 21 1 5 6 1 6 1,152 1 1,153 1,153 2 2 2 0 0 November 22 1 5 6 5 1,152 1,153 1,152 2 2 2 0 0 November 23 4 5 5 1,152 1,152 1,152 2 2 2 0 0 November 24 4 5 4 1,151 1,152 1,151 1 2 2 0 0 November 25 5 6 5 1 1,151 1,152 1 1,152 2 3 3 0 0 November 26 5 6 5 1,151 1,152 1,152 3 3 3 0 0 November 27 1 5 5 5 1,151 1,151 1,151 2 3 3 0 0 November 28 5 5 5 1,151 1,151 1,151 2 2 2 0 0 November 29 5 5 5 1,150 1,151 1,151 2 2 2 0 0 November 30 5 5 5 1,150 1,151 1,150 2 2 2 0 0 December 1 4 5 5 1 1,150 1,150 1,150 2 2 2 0 0 December 2 5 5 5 1,150 1,150 1,150 2 2 2 0 0 December 3 5 5 5 1,149 1,150 1,150 2 2 2 0 0 December 4 4 5 4 1,149 1,150 1,149 1 2 2 0 0 December 5 4 5 5 1,149 1,150 1,149 2 2 2 0 0 December 6 4 5 4 1,148 1,150 1,149 1 2 1 0 0 December 7 4 4 4 1,148 1,149 1,148 1 1 1 0 0 December 8 4 4 4 1,147 1,148 1,148 1 1 1 0 0 December 9 3 4 4 1,147 1,148 1,147 1 1 1 0 0 December 10 3 4 3 1,146 1 11147 1,147 1 1 1 0 0 December 11 3 4 4 1,146 1,147 1,146 0 1 1 0 0 December 12 4 5 5 1,147 1,148 1,147 1 2 2 0 0 December 13 5 6 5 1,147 1,148 1,148 2 3 3 0 0 December 14 1 4 5 1 5 1,147 1,148 1,147 1 3 2 0 0 December 15 4 5 5 1 1,147 1,147 1 1,147 1 2 2 0 0 December 16 3 5 4 1,145 1,147 1,146 0 2 1 0 0 December 17 3 4 4 1,145 1,145 1,145 0 1 1 0 0 December 18 3 4 4 1,145 1,145 1,145 1 1 1 0 0 December 19 4 5 1 4 1,145 1,145 1,145 1 2 1 0 0 December 20 4 6 5 1,145 1,145 1,145 1 2 2 0 0 December 21 5 6 5 1,145 1,145 1,145 2 3 3 0 0 December 22 5 6 6 1,145 1,145 1,145 3 3 3 0 0 December 23 5 6 6 1,145 1,145 1,145 3 3 3 0 0 December 24 5 6 6 1,145 1,145 1,145 3 5 4 0 0 December 25 5 6 6 1,144 1,145 1,144 5 6 6 0 0 December 26 5 6 6 1,144 1,144 1,144 6 6 6 0 0 Caelus Natural Resources Alaska, LLC Page 19 December 1 27 5 6 6 1,143 1,144 1 1,144 6 7 7 0 0 December 28 5 6 6 1,143 1,143 1,143 7 8 7 0 0 December 29 6 7 6 1,143 1,144 1,144 8 10 9 0 0 December 30 5 6 6 1,143 1,144 1,143 9 10 10 0 0 December 31 5 5 5 1,142 1,143 1,142 9 10 9 0 0 15,272 6/21/2014 to 6/23/2014Slickline on T46i to perform a SBHP survey. Hydrate obstruction in the tubing; pump -in to clear. 8/23/2014 Data invalid, noise. The few one minute spikes are all independent. The trends before and after the spikes are consistent. Caelus Natural Resources Alaska, LLC Page 20
