oglan-2 dir operations geology program rev4 mayl2014

Well: OGLAN-2 DIR OPERATIONS GEOLOGY PROGRAM

Rev.4: further to Well Cellar Surface Location (IGM Certified) Topographic Measurements

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Update: May 2014

Agip Oil Ecuador (Agip Oil Ecuador 100%) 4

OPERATIONS GEOLOGY PROGRAM The present document is CONFIDENTIAL and it is the property of Agip Oil Ecuador

It shall not be shown to third parties nor used for reasons different from those for which it is issued.

OPERATIONS GEOLOGY PROGRAM




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Update: May 2014




DISTRIBUTION LIST

MRNR - Ministerio de Recursos No Renovables 2 Copies SHE Secretaria de Hidrocarburos del Ecuador ARCH - Agencia de Regulacin y Control de Hidrocarburos

AGIP OIL ECUADOR 3 Copies Exploration Dptm Reservoir Dptm Well Operations Dptm

Eni S.p.A. (E&P) 4 Copies ESAM NAME COAP/ESA GEOP

Date of issue: April 2014

Issued by GEOP Author R. AMRI Operations Geologist

Checked by R. CERRI / G. BAGNOLI Operation Geology Senior Advisor E. ARELLANO AOE Operations Geologist

Approved by

G. VENTURINO AOE Exploration Manager A. MALOSSI GEOP Manager



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INDEX

1.0 HEALTH, SAFETY AND ENVIRONMENT ............................................................................. 5 2.0 GENERAL WELL DATA ......................................................................................................... 6 3.0 LITHOSTRATIGRAPHIC PROGNOSIS ................................................................................. 7

3.0.0 Formations/Depths .............................................................................................................. 7 3.1.0 Lithological description ........................................................................................................ 8

4.0 SURFACE LOGGING ........................................................................................................... 12 4.0.0 Surface logging specification ............................................................................................. 12 4.1.0 Reporting ........................................................................................................................... 12

5.0 SAMPLING AND DATA ACQUISITION ............................................................................... 15 5.0.0 Cuttings .............................................................................................................................. 15 5.1.0 Gas While Drilling (GWD) .................................................................................................. 16 5.2.0 Log While Drilling (LWD) ................................................................................................... 16 5.3.0 Fluid Sampling ................................................................................................................... 16 5.4.0 Bottom Hole Coring Program ............................................................................................ 16 5.5.0 Sidewall cores .................................................................................................................... 16

6.0 WIRELINE LOGGING & TESTING ...................................................................................... 17 6.0.0 Open hole logging .............................................................................................................. 17 6.1.0 Wireline testing (MDT) ....................................................................................................... 17 6.2.0 Formation testing ............................................................................................................... 17 6.3.0 Well seismic survey ........................................................................................................... 17 6.4.0 General Recommendations ............................................................................................... 18

7.0 DATA ANALYSES AND STUDIES ...................................................................................... 19 8.0 REFERENCE WELL ............................................................................................................. 20 9.0 PRESSURE AND TEMPERATURE PROGNOSIS .............................................................. 21

9.0.0 Pressure Gradient .............................................................................................................. 21 9.1.0 Temperature gradient ........................................................................................................ 21

10.0 CIRCULATION LOSSES ...................................................................................................... 21 11.0 SPECIAL INSTRUCTION ..................................................................................................... 22

11.0.0 File nomenclature for FIELD DELIVERY .......................................................................... 22 11.1.0 Mud Logging ...................................................................................................................... 23 11.2.0 File standard format vs. Depth .......................................................................................... 24 11.3.0 File standard format vs. Time ............................................................................................ 26 11.4.0 Fluorescence Description .................................................................................................. 28



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FIGURES

Figure 1: OGLAN-2 DIR Prognosis ................................................................................................ 12 Figure 2: Oglan Cross-Section (pre-Drilling Oglan-2 Dir) ................................................................. 20

TABLES

Table 1: Formation Tops ..................................................................................................................... 7 Table 2: Lithology Description ......................................................................................................... 8-9 Table 3: Well Main Targets. 10 Table 4: GWD data Depth base ..................................................................................................... 13 Table 5: Lithological Data Displaying_Model-1 and Model-2 ........................................................... 14 Table 6: Lithological Sampling .......................................................................................................... 15 Table 7: Logging Program ................................................................................................................. 17 Table 8: Data Depth........................................................................................................................... 25 Table 9: Data Time ............................................................................................................................ 27 Table 10: Fluorescence Description .................................................................................................. 29 Table 11: Samples / Documents Distribution .................................................................................... 30



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1.0 HEALTH, SAFETY AND ENVIRONMENT

The following program summarizes different Operations Geology activities for the exploratory well OGLAN-2 DIR.

SAFETY is considered the HIGHEST PRIORITY during all different jobs.

All Procedures must be in compliance with eni HSE policy. This document provides guidelines for safe and efficient operations in all aspects of operations.

All activities carried out by different CONTRACTORS shall be performed in accordance with CONTRACTORs written procedures and in compliance with the Applicable Documents and with the COMPANY requirement defined in the ITT (Invitation To Tender).

For any detail, eni representatives (company man, wellsite geologist...) are available to highlight it.



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2.0 GENERAL WELL DATA

ITEM DESCRIPTION Country ECUADOR Block Block 10 Operator Agip Oil Ecuador B.V. (100%) Area / Province Oriente / Pastaza Indigenous Local Community Shuar Washinz (belonging to ACIA Community Association) Environmental / Logistics Onshore / Amazonic Rain Forest / Heli-transported Basin Oriente Prospect Oglan Discovery (1972, by Anglo) Well Type Exploratory / Appraisal / Onshore / Deviated

Surface Location * PSAD 56 (equivalent to Hayford 1909) UTM Zone 18 S

Ground Level Elevation R.T.E. (Rig PTX-20) R.K.B. Elevation (Assumed)

Lat. = 01 20 37.4904 S (1.3437473 S) Long. = 77 40 11.5894 W (77.6698859 W) X = 202,869.844 m E Y = 9,851,311.220 m N 2,541.7 ft (774.7 m) M.S.L. 25.7 ft (7.8 m) 2,567.4 ft (782.5 m) M.S.L.

Target Location Coordinates (Top Main Hollin Fm Sand 1 Entry Point, Seismic Line S-34 CDP 92) PSAD 56 (equivalent to Hayford 1909) UTM Zone 18 S

Lat. = 01 20 44.39 S (1.34566389 S) Long. = 77 40 20.47 W (77.67235278 W) X = 202,595.3 m E Y = 9,851,098.9 m N

Proposed Total Depth 6,321 ft MD / 6,094 ft TVD / -3,525 ft TVDSS 1,926.6 m MD / 1,857.4 m TVD / -1,074.4 m TVDSS

Depth to Target 5,856 ft MD / 5,659 ft TVD / -3,091 ft TVDSS 1,784.8 m MD / 1,725.0 m TVD / -942.0 m TVDSS K.O.P. incl. Horizontal Displacement @ Target Depth Horizontal Displacement @ TD

2,100.0 ft MD TVD / -469 ft TVDSS 20.9 SW 1,135 ft (346 m) 1.301 ft (397 m)

Trap Type Structural (Compressional) Target (Fm / Lithology / Age) Main Hollin / Sst / Lower Cretaceous Sealing Rock (vertical and lateral) / Source Rock Napo Fm Structural Areal / Vertical Closure 10.5 SqKm / 368 ft (112 m) Hydrocarbon Column 261 ft OWC -3.464 ft Reservoir Petrographic Parameters: Porosity / Sw / N/G / Bo

Hollin Fm Sst. Net Reservoir 23 % / 27% / 88% / 1.03

Hydrocarbon Type 11 13 API degree Oil O.O.I.P. 316 Mbbls Mean Resources (R.F.) 38.2 Mbbls (11.9%) POS 72% Risked Mean Resources 27.5 Mbbls

Distances from site (km / time) CPF (logistic Base): 9 Km / 5 min. helicopter Puyo: 39 km / 25 min. helicopter Puyo CPF (road): 32 Km / 1 hour Quito CPF (road): 270 Km / 6 hours

Drilling Rig Petrex-20 (heli-transportable) *: further to Well Cellar Surface Location (IGM Certified) Topographic Measurements



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3.0 LITHOSTRATIGRAPHIC PROGNOSIS

Predicted depths and formation tops, referred to MD, TVD (Rotary Table assumed elevation: +2567.4 ft; Ground Level elevation: +2541.7 ft) and TVDSS, are listed below:

3.0.0 Formations/Depths

The well is planned to be drilled as slightly deviated hole (20.9 SW until TD, KOP 2100 ft MD) in order: to take cores on the primary target Lower Cretaceous Sandstone of the Hollin Fm, with an

horizontal displacement at target depth of 1135 ft (346 m); to reach the total depth of 6321 ft MD, 6094 ft TVD, -3525 ft TVDSS, within the igneous rocks of

the Basement, with an horizontal displacement at TD of 1301 ft (397 m).

In any case, the final well TD will be decided according to hydrocarbon shows and real time interpretation of Gas While Drilling (GWD) and Logging While Drilling (LWD).

The well prognosis is summarized in the table below and in the Fig. 1.

Formation Tops

Depth ft MD

Depth ft TVD

Depth ft TVDSS

Thickness ft MD

Thickness ft TVD

Arajuno 26 26 2543 1223 1223 Chalcana 1249 1249 1320 643 643 Orteguaza 1892 1892 677 605 604 Tiyuyacu 2497 2496 73 1147 1098 Tena 3645 3594 -1025 1403 1310 Napo 5047 4904 -2335 767 717 Top Napo T 5517 5343 -2774 146 136 Base Napo T 5662 5479 -2910 - - Upper Hollin 5814 5621 -3052 41 39 Main Hollin 5856 5659 -3091 359 335 Chapiza / Basement 6215 5995 -3426 >106 >99

Expected TD 6321 6094 -3525 **** ****

Tab. 1: Formation Tops



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3.1.0 Lithological description

FORMATION (Age) Interval ft MD Thickness

ft MD Lithology: Description

ARAJUNO (L. Miocene) 26-1249 1223

Sandstones with interbedded claystones and siltstones.

The sandstone levels are more common in the upper part

and become thinner and less frequent in the lowermost

part. The claystones are predominantly brown or gray

and non-calcareous.

CHALCANA (Oligo-Miocene) 1249-1892 643

Predominance of red claystones, characterized by traces

of anhydrite, with rare silty or thin sandy beds, which

become more significant towards the base. The claystone

are typically orange-brown or reddish-brown, non-

calcareous and normally with significant nodular

inclusions or lamina of anhydrite.

ORTEGUAZA (Oligo-Miocene) 1892-2497 605

The upper part is characterized by thin layers of

sandstone and then from the top and bottom the

presence of claystone is absolute with colors as

predominant reddish brown and purple, soft and massive.

and non calcareous.

TIYUYACU (Eocene) 2497-3645 1147

Cherty conglomeratic sandstones, interbedded with thick

claystones levels. Some of the pebbles are purely quartz,

but the bulk of them is tan, yellow, black, reddish black

colored chert and well rounded. The chert is particularly

abundant in the basal conglomerates and the matrix is

varicolored clay and silt.

TENA (Paleocene-Eocene) 3645-5047 1403

Calcareous claystones with interbeds sandstones and

minor limestones near the top and marly claystone near

the base. The claystones at the top are orange-brown

and/or yellowish-brown. Throughout the section, are

reddish-brown or yellowish-brown, with minor light gray,

cream or beige and occasionally mottled.



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NAPO (Cretaceous) 5047-5814 767

Composed of dark gray fissile shales, predominantly light

colored fine-grained limestone, and locally glauconitic

sandstones. These Cretaceous marine sediments

contrast dramatically with the overlaying Tertiary

continental sedimentation (red beds). Any description of reddish cuttings is due to sample contamination by

caving.

HOLLIN (L. Cretaceous) 5814-6215 400

* The Upper Hollin Mb represented with glauconitic, silty

limestone, shale, coal and tight siltstone to sandstone.

* The Main Hollin Mb (5856 ft MD) represents the target of the well. These normal porous and permeable

quartzose sandstones were generally well stained with

dark brown to black oil.

The member is essentially quartzose, coarse grained,

well sorted, with subangular grains. It has been

recognized a general trend fining upward, with a kaolinitic

matrix that becomes more important in the middle and

lower part of the member.

CHAPIZA / Basement

(Pre-Cretaceous) 6215-6321

(TD) >106

The top of the Jurassic Chapiza Fm at 6509 ft is

questionable in Oglan A-1 as it is based on a poor

correlation and a reported occurrence of anhydrite in a

sidewall core taken at 6522 ft. ANGLO geologists have

extended the Hollin Fm down to 6555 ft. The section

between 6512 and 6522 ft has been described as

siltstone: white to green, argillaceous, generally non-

calcareous with thin inter-beds of dark grey shale and

brittle coal.

From about 6300 ft mainly slightly altered igneous rock

having a large percentage of angular quartz, red and

orange feldspar. Minor amounts of biotite and chlorite

were also present.

Tab. 2: Lithology Description



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FORMATION AGE LITHOLOGY Depth ft MD Depth ft TVD

Depth ft TVDSS COORDINATES

MAIN HOLLIN L. Cretaceous Sandstone 5856 5659 -3091

X: 202595.3 m E Y: 9851098.9 m N

Tab. 3: Well Main Targets



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D EPOSITION A L EN V IR ON M EN T CASING

(MD)26 26 2543 Csg. 20"

150'

ARAJUNO

1249 1249 1320

1892 1892 677 CHALCANA

2497 2496 73

TIYUYACU

3645 3594 -1025

TENA

5047 4904 -2335

5180'

NAPO

5814 5621 -3052

5856 5659 -3091

MAIN HOLLIN

6215 5995 -3426C ON T. / IGN EOU S C HA PIZA / B A SEM EN T

6321 6094 -3525 TD @ 6321'

G.L. = 2541.7 ft Lower Orteguaza: abrasive for bits

R.K.B. = 2567.4 ft Lower Tiyuyacu: severe cherty conglomerateT.D. = 6321 ft / 6094 ft TVD / -3525 ft TVDSS Tena Fm: Reactive clays (swelling)

Napo Basal: Fissile shalesW&D = Washed and Dried Contingent Cores on Napo T

W / U = Wet / Unwashed Cores on Hollin

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Fig. 1: OGLAN-2 DIR Prognosis

4.0 SURFACE LOGGING

4.0.0 Surface logging specification The surface logging service will start from the spud-in of the well and will continue until the end of the operations. It will be defined as follows: OPERATING service, from the spud-in of the well to the end of the drilling phase. REDUCED service, after RIH production casing liner and cementing job or abandonment phases. The surface-logging unit will be conform to Eni technical specifications and will assure all the operations established in the contract, according to the Eni standard procedures, as per instructions given to the Contractor. Special attention will be dedicated to the installation, calibration and maintenance of the instrumentation of detection and acquisition of gas shows. Furthermore the maximum of the attention is required to the calibration and maintenance of the sensors monitoring all the safety parameters.

4.1.0 Reporting Upon completion of the installation of the logging unit and the equipment, the Contractor is required to provide the Company man with the Rig up Report, where all the procedures of calibration used have to be reported; possible anomalies, not in line with technical specifications required by the contract, will be pointed out. All geological reporting produced at well site by the personnel of the Surface Logging Contractor will be compiled in due time in order to have always updated data and edited data; particularly: - The daily geological report will cover all operations and important facts from 00.00 to 24.00

hours of the previous day, with a note updating operations and important facts from 00.00 hours to 07.00 hours of the same day. The daily geological report will be handed to the Company man who will take care of transmitting it to the Quito office.

- The Master Log, always updated, will be handed to the Wellsite Geologist and/or to the Company Man in PDF format.

- The Sigma Log, always updated, will be handed to Wellsite Geologist and/or the Company Man in PDF format.



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- The GWD data (see Tab. 4) and the drilling parameters in Depth base (each 0.2m sampling rate) and Time base (each 7 seconds sampling rate) in an ASCII or EXCEL format will be handed to the Wellsite Geologist and/or the Company Man with the daily geological report.

CURVE MNEMONICS

Standard units of measure

Description note

DEPTH ft/RT Depth bit (meas) DEPTH TVD ft/RT Depth bit (vert) TG ppm Total Gas See note (**) C1 ppm Methane See note (***) C2 ppm Ethane See note (****) C3 ppm Propane See note (****) iC4 ppm I Butane See note (****) nC4 ppm N Butane See note (****) iC5 ppm I Pentane See note (****) nC5 ppm N Pentane See note (****) ROP ft/h Rate of Penetration (avg) WITS Item descr. 2.10 FLOW IN gal/min Mud Flow IN (avg) WITS Item descr. 2.19 MW IN ppg Mud Density IN (avg) WITS Item descr. 2.17 WOB lbs Weight on bit (surf,avg) WITS Item descr. 2.11 BIT SIZE Inch Bit size WITS Item descr. 21.9 Please Respect column order, Titles and Units

Tab. 4: GWD data Depth base

- The lithological data in EXCEL format (see Tab. 5) will be provided at the end of each drilling phase, but should be also provided based on client request.

- All data must be loaded in at the earliest, and however not later than 07:00 hours. - At the end of the well the Surface Logging Contractor will send to the Company a final report

(five paper copies), including all the geological and the engineering data of the well accompanied by a CD-ROM gathering all the digital data (Depth and Time scales) relevant to the well (GWD EXCEL file data, lithology EXCEL file, drilling parameters in ASCII or EXCEL file, Final Master log in CONTINUE PDF format, Final Sigma Log in CONTINUE PDF format, all daily reports and the final geological report).



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DEPTH DOLOMITE SHALE CLAY LMST SALT SILT

SILTSTONE SAND SANDSTONE ANHYDRITES MARL SILTY CLAY TOTAL

(ft) % % % % % % % % % % % 115 20 0 80 0 0 0 0 0 0 0 100

Please respect the ten (10) lithologies of the table. Each different lithology must be included in one of the ten lithologies of the table. Check that the total is equal to 100% N.B: No empty cells: Each cell must contains a value even 0.

Tab. 5: Lithological Data Displaying_Model-1 and Model-2

TOP (ft) BOTTOM (ft) LITHOLOGY TYPE LEFT (%) RIGHT (%)

4500 4530 Sandstone 0 100 4530 4560 Sandstone 0 70 4530 4560 Shale 70 90 4530 4560 anhydrite 90 100



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5.0 SAMPLING AND DATA ACQUISITION

5.0.0 Cuttings Ditch cuttings will be collected according to the following procedures: Sampling will start with the 16 drilling phase (approximately from 100 ft). Sampling rate, for all series of samples will depend on the rate of penetration, and on the hydrocarbons shows, but generally as follows: - Every 30ft through the 16 and 12 1/4 drilling phases. - Every 10ft through the 8 1/2 drilling phase (to T.D.). The sampling rate may however be modified at the well site by the Well Site Geologist or Quito Exploration or Reservoir Dptms. The quantity of cuttings to be collected at the shale-shaker will be at least of about pounds for each series.

DEPTH INTERVAL (ft MD) SETS N

SAMPLING (ft)

TYPE OF SAMPLE DISTRIBUTION

From Surface to 5180 ft A-B-C-D 30 ft Washed and dried ENI/Partners From Surface to 5180 ft A-B-C-D 30 ft Wet /unwashed ENI/Partners From 5180 ft to TD A-B-C-D 10-15 ft Washed and dried ENI/Partners From 5180 ft to TD A-B-C-D 10-15 ft Wet /unwashed ENI/Partners

Tab. 6: Lithological Sampling

Each sample will be labeled as follows:

. Agip Oil Ecuador

. Name of the well (OGLAN-2 DIR)

. Depth of sample

. Type of sample (washed and dried / unwashed)

The whole sets of washed and dried samples will be shipped to:

Agip Oil Ecuador B.V. Ecuador Branch CPF Operation Base



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5.1.0 Gas While Drilling (GWD) While drilling the gas data should be registered as for Eni's procedures by means of QGM (Quantitative Gas Measurement) or Constant Volume Trap, a FID (Flame Ionization Detector) and a Fast Gas Chromatograph.

5.2.0 Log While Drilling (LWD) Phase 16

RUN INTERVAL ft MD LOG STRING NOTE

1 150 - 1925 GR-Resistivity WBM (Water Base Mud) Phase 12 1/4


1 1925 - 5180 GR-Resistivity WBM (Water Base Mud) Phase 8 1/2


1 5180 6321 (TD) GR-Resistivity (LLG) / GR- Resistivity (LLG) on Bit WBM (Water Base Mud)

5.3.0 Fluid Sampling All fluids will be sampled as for Eni's procedures and will be sent to the CPF Operation Base of Agip Oil Ecuador (see page 14) or, on request, to MILAN at the following address: GEOLAB - Att. Michele Impal Laboratori Bolgiano - Via Maritano 26 20097 - SAN DONATO MILANESE - ITALY

5.4.0 Bottom Hole Coring Program Coring job has been planned in Hollin Fm for reservoir purposes (results will be incorporated to a preliminary Static and Dynamic Model). Contingent coring will be possibly performed in Napo T Sandstones. Both core intervals, related coring points, coring technique and procedures will be specified and detailed in a dedicated core protocol delivered as a separate document at due time.

5.5.0 Sidewall cores Following log analysis and bottom hole core results, sidewall cores might be cut.



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6.0 WIRELINE LOGGING & TESTING

6.0.0 Open hole logging Service Company: Schlumberger Measure unit: feet Recording scales: 1:500 / 1:200

Phase 8 1/2


1 5180 - TD HRLA - PEX (GR - HGNS - TLD - MCFL - CAL) open hole 2 5180 - TD FMI - MSIP (Dipole Sonic) - GR open hole 3 5180 - TD ADT - CMR - GR open hole

4 5180 - TD MDT Saturn - GR open hole

cont. 5180 - TD MSCT - GR (contingent) open hole 5 9 5/8 Csg. CBL - VDL - GR - CCL cased hole

6 7 Liner USIT - CBL - VDL - GR - CCL cased hole

7 VSI - GR (Check Shots) cased hole

Tab. 7: Logging Program

6.1.0 Wireline testing (MDT)

Wireline testing, both pressure measurements and formation sampling, will be performed in the potential hydrocarbon bearing zones. A dedicated MDT Saturn program will be defined before the job.

6.2.0 Formation testing

Production testing will be carried out in the hydrocarbon bearing intervals upon logs, GWD and MDT measurements interpretations. In case of oil bearing interval discovery, fluid sampling for PVT analysis purpose will be considered.

6.3.0 Well seismic survey

At TD the Seismic Check Shots will be carried out most likely in cased hole (if 7 casing will be set).



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Update: May 2014




Source: Air gun Shooting Interval: taking into account the completely structural nature of the target horizons and the availability of 2D Seismic only, a large shooting interval will be considered from TD up to surface, with a smaller detailed interval in front of Napo Fm (depending also to the casing cement quality).

6.4.0 General Recommendations

A mud sample will be collected during the last circulation prior to logging operations, in order to measure Rm, Rmf and Rmc. A repeat section of around 250ft over the most significant zone must be recorded. The sonic and the Caliper will be checked in cased hole, in order to control the reliability of the reading. The density/neutron logs will be recorded in limestone scale, using a range of 1,95 / 2,95 gr/cc for Density and 15 / 45 porosity units for the Neutron log. The running sequence of the logs to be registered could be modified by the Operator or dictated by unforeseeable operational constraints and problems. Five days prior to the CMR registration, 2 ditch magnets will be installed in the mud flow line after the shale shakers. The magnets will be regularly cleaned. The Service Company will provide at well site, after each logging operation, the following documents: - 5 color paper copies - 1 CD with DLIS, ASCII and PDS format digital data.



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7.0 DATA ANALYSES AND STUDIES

The following data computations and studies might be performed: - Processing and interpretation of USIT. - Gas while drilling (GWD) interpretation in the 8 target phase. - CPI over the hydrocarbon bearing zones (ADT CMR included). - Processing of well seismic. - Petrographic and petrophysical analysis (on cuttings, core and probable sidewall cores).



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Update: May 2014




8.0 REFERENCE WELL

The reference well is OGLAN A-1, located about 750 m to the NEN of Oglan-2 Dir target location. A SSW-NNE geological cross-section through Oglan A-1 and Oglan-2 Dir Prognosed Top Target Location is represented in Fig. 2.

Fig. 2: Oglan Cross-Section (pre-Drilling Oglan-2 Dir)



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Update: May 2014




9.0 PRESSURE AND TEMPERATURE PROGNOSIS

9.0.0 Pressure Gradient

No abnormal pressures are expected down to the well TD.

9.1.0 Temperature gradient

The temperature gradient should match the normal geothermal gradient. Temperatures not higher than 150F are expected at T.D.

10.0 CIRCULATION LOSSES

In more than 20 wells drilled on the Villano Field, only in 2 wells occurred some losses while drilling the shallowest outcropping Plio-Quaternary Mesa-Mera Fm, which in Oglan-2 Dir location it is forecast to be absent.



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Update: May 2014




11.0 SPECIAL INSTRUCTION

11.0.0 File nomenclature for FIELD DELIVERY

MudLogging:

- Data Depth (GWD): top_btm_WellName(short)_D.xls/ascii (example 2320_2420_OGLAN-2 DIR_D.xls/asc) - Data Time: date_WellName(short)_TIME.xls/asc (example 300107_OGLAN-2 DIR_Time.xls/asc) - Masterlog: top_btm_WellName(short)_ML.pdf, "MLV" if the masterlog is verticalizated (example 2320_2420_OGLAN-2 DIR_ML.pdf). - Hydrocarbons Log (Gaslog): top_btm_WellName(short)_Hydro.pdf (example 2320_2420_OGLAN-2 DIR_Hydro.pdf) - Sigma or Dexponent will be this: top_btm_WellName(short)_Dexp.pdf (example 2320_2420_OGLAN-2 DIR_Dexp.pdf).

LWD logging:

- Log MD 500 scale: WellName(short)_LWD_M5_ top_btm_RT.pdf or pds (example OGLAN-2 DIR_LWD_M5_2305_2476_RT.pdf) - Log MD 200 scale: WellName(short)_LWD_M2_ top_btm_RT.pdf or pds (example OGLAN-2 DIR_LWD_M2_2305_2476_RT.pdf) - Log TVD 500 scale: WellName(short)_LWD_V5_ top_btm_RT.pdf or pds (example OGLAN-2 DIR_LWD_V5_2305_2476_RT.pdf) - Log TVD 200 scale: WellName(short)_LWD_V2_ top_btm_RT.pdf or pds (example OGLAN-2 DIR_LWD_V2_2305_2476_RT.pdf) - LAS or DLIS data: WellName(short)_LWD_ top_btm_RT.las (example OGLAN-2 DIR_LWD_2305_2476_RT.las) After down loading memory in the file name, RM (Record Memory data) replaces RT (Real Time data) - Survey data: WellName(short)_SURVEY_btm.xls (example OGLAN-2 DIR_SURVEY_2476.xls)



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WLL logging:

- Log MD 500 scale: WellName(short)_LogName(StringReference)_M5_ top_btm_RC.pdf or pds (example OGLAN-2 DIR_HRI_M1_2305_2476_RC.pdf) - Log MD 200 scale: WellName(short)_LogName(StringReference)_M2_ top_btm_RC.pdf or pds (example OGLAN-2 DIR_HRI_M2_2305_2476_RC.pdf) - Log TVD 500 scale: WellName(short)_LogName(StringReference)_V5_ top_btm_RC.pdf or pds (example OGLAN-2 DIR_HRI_V1_2305_2476_RC.pdf) - Log TVD 200 scale: WellName(short)_LogName(StringReference)_V2_ top_btm_RC.pdf or pds (example OGLAN-2 DIR_HRI_V2_2305_2476_RC.pdf) - LAS or DLIS data: WellName(short)_LogName(StringReference)_RC.las (example OGLAN-2 DIR_HRI_2305_2476_RC.las) FC (FINAL COPY data) replace RC (RUSH COPY data) in the final delivery.

11.1.0 Mud Logging

1. The following information must be reported as soon as finalized: Final Rig Position, and RTE. 2. The dry and wet samples will be placed in cardboard boxes (dry samples) or wooden boxes (wet samples) clearly marked. 3. The washed and dried samples will be approximately pounds and packed in paper or plastic bags. 4. The wet samples will be of minimum pounds and packed in plastic bags and placed inside cloth bags. 5. On each plastic and paper bag, cardboard box and wooden box have to be specified:

-Customer name -Well name and number -Sample depth

6. Agip Oil Ecuador wellsite geologist may alter samples interval or distribution instructions if necessary. 7. Supplementary intermediate samples will be taken in the following cases:

-unexpected HC shows -nearby formation boundaries which affect operation continuation (Csg points, coring points...). -unexpected significant variations in the drilling speed (drilling break, reverse break)

8. Check the samples for the presence of fluorescence and define it as shown in Tab. 10.



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9. The following plots and data are to be provided by the mud logging contractor daily by mail: -Master log (pdf format) -Hydrocarbon log (pdf format) -Dexponent (pdf format) -Depth File / GWD (ASCII or xls format) -Time file (ASCII or xls format) -Mud Losses Data

The gas curve will be presented as normalized gas curves. The QGM raw gas data (Total gas) value will be normalized (corrected for ROP, Flow rate and bit size) by applying the following algorithms: Normal Gas value = 14.71*(TG*Flow rate*0.2642) / (ROP*(Bit Size)2) TG = Total gas in percentage (%) ROP = Rate of penetration in ft/hr Flow rate = gal/min Bit Size = inches Normal gas = %

10. The wellsite geologist should check instrumentation daily and complete monthly mudlogging quality control forms which should be sent to the office. Special attention should be given to sample labeling. 11. One CD containing gas and fluorescence shows, drilling parameters and lithology data together with five paper prints of each plot should be dispatched to the district office at the end of each drilling phase. In addition an up to date master log must be e-mailed daily to the district office at 7:00 with the daily geological report. 12. The senior mud logger will be responsible for transmitting daily geological reports in the absence of Agip Oil Ecuador wellsite geologist. 13. Mud loggers are responsible for collecting all cutting samples as per program. 14. Mud loggers will assist the Agip Oil Ecuador geologist in catching, preserving and describing any conventional and sidewall cores. 15. A record of the samples movement from the rig should be filled at wellsite and also transmitted to the office. 16. Agip Oil Ecuador wellsite geologist should fill out the specified reports as per norms and procedures for wellsite assistance.

11.2.0 File standard format vs. Depth



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All acquired data shall be stored systematically on an appropriate media in LAS format Vers.2.0 (compatible with Microsoft Operating Systems Windows ME/NT/2000/XP) and shall be delivered daily or on Company request. At the end of the well activities, the final report and the CD-ROM with all acquired data shall be delivered. The file will contain the following indicators:

CURVE MNEMONICS

Standard units of measure

Description note

DBTM ft Depth bit (meas) DBTV ft Depth bit (vert) ETIM s Elapsed Time Time in Seconds GAST ppm Total Gas See note (**) C1 ppm Methane See note (***) C2 ppm Ethane See note (****) C3 ppm Propane See note (****) iC4 ppm I Butane See note (****) nC4 ppm N Butane See note (****) iC5 ppm I Pentane See note (****) nC5 ppm N Pentane See note (****) ROPA ft/h Rate of Penetration (avg) WITS Item descr. 2.10 MFIA gal/min Mud Flow IN (avg) WITS Item descr. 2.19 MFOA gal/min Mud Flow OUT (avg) WITS Item descr. 2.20 MFOP % Mud Flow Out % WITS Item descr. 2.21 MDIA ppg Mud Density IN (avg) WITS Item descr. 2.17 MDOA ppg Mud Density OUT (avg) Density of the mud leaving the hole,

averaged over the interval BDIA Inch Bit size WITS Item descr. 21.9 WOBA lb Weight on bit (surf,avg) WITS Item descr. 2.11 HKLA lb Hookload (avg) WITS Item descr. 2.12 M_LS gal/min Mud Losses Mud Losses Rate M_LT bbl Mud Losses Total losses of the sampling interval TVA bbl Tank volume (active) WITS Item descr. 2.22 SPPA psi Stand Pipe Pressure WITS Item descr. 2.14 TQA lbft Rotary torque (surf, avg) WITS Item descr. 1.18 RPMA rpm Rotary speed (surf, avg) WITS Item descr. 2.15 TRPM rpm Bit revolution (downhole) Motor + rotary/top drive MTOA degF Mud Temperature Out (avg) Temperature of the mud leaving the hole,

averaged over the interval MTIA degF Mud Temperature In (avg) Temperature of the mud entering the hole,

averaged over the interval Q2PC (*) % QFT2 - Weight % oil Optional Q2AP (*) API QFT2 - Oil API gravity Optional QFT1 (*) iu QFT - Fluores. intensity unit Optional ECD at BD ppg D Exp

Tab. 8: Data Depth

NOTE:



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(*) When available (**) TG & Chromatographic Data must be referred at the same sampling depth (***) The highest C1 value recorded in the depth interval (****) Value associated to the C1 value of the same Chromatographic cycle

o Depth database without gas events as: Trip gas, PCG, calibration etc. o Prepare file containing these special gas events (Trip gas, PCG, Calibration, etc.).

1. The sampling rate must be constant at max every 20/25 cm or 1 foot. 2. The NULL VALUE (0) must be inserted in the correspondent parameter column even if the

data is either not acquired or is null. 3. Decimal separator will be the point. 4. Data must not be expressed or inserted with exponential format. 5. No empty lines must be inserted at the beginning, inside or at the end of the lines. 6. The date/time format for LAS 2.0 Header must be: DD/MM/YYYY HH-MM-SS 7. The U.W.I. for LAS 2.O Header must be as per Eni E&P Division Unique Well Identification

code (five digits). 8. The file name must be: Top _ Btm (interval data) _Well Name_D (depth). LAS or XLS

11.3.0 File standard format vs. Time



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All acquired data shall be stored systematically on an appropriate media in LAS format Vers.2.0 (compatible with Microsoft Operating Systems Windows ME/NT/2000/XP) and shall be delivered daily or on Company request. At the end of the well activities, the final report and the CD-ROM with all acquired data shall be delivered. The file will contain the following indicators: CURVE MNEMONICS

standard units of measure

Description note

ETIM s Elapsed Time Time in Seconds DBTM ft Depth bit (meas) WITS Item descr. 1.8 DBTV ft Depth bit (vert) WITS Item descr. 1.9 DMEA ft Depth hole (meas) WITS Item descr. 1.10 DVER ft Depth hole (vert) WITS Item descr. 1.11 BPOS ft Block position WITS Item descr. 1.12 ROPA ft/h Rate of Penetration (avg) WITS Item descr. 1.13 HKLA lb Hookload (avg) WITS Item descr. 1.14 HKLX lb Hookload (max) WITS Item descr. 1.15 WOBA lb Weight on bit (surf,avg) WITS Item descr. 1.16 WOBX lb Weight on bit (surf, max) WITS Item descr. 1.17 RPMA rpm Rotary speed (surf, avg) WITS Item descr. 1.20 TRPM rpm Bit revolution (downhole) Motor+rotary/top drive TQA lbft Rotary torque (surf, avg) WITS Item descr. 1.18 TQX lbft Rotary torque (surf, max) WITS Item descr. 1.19 MDIA ppg Mud Density IN (avg) WITS Item descr. 1.32 MDOA ppg Mud Density OUT (avg) WITS Item descr. 1.31 MFIA gal/min Mud Flow IN (avg) WITS Item descr. 1.30 MFOA gal/min Mud Flow OUT (avg) WITS Item descr. 1.29 MFOP % Mud Flow Out % WITS Item descr. 1.28 SPM1 nr Pump stroke rate 1 WITS Item descr. 1.23 SPM2 nr Pump stroke rate 2 WITS Item descr. 1.24 SPM3 nr Pump stroke rate 3 WITS Item descr. 1.25 STKC nr Pump stroke Count (cum) WITS Item descr. 1.37 SPPA psi Stand Pipe Pressure WITS Item descr. 1.21 CHKP psi Casing (Choke) Pressure WITS Item descr. 1.22 TVA bbl Tank volume (active) WITS Item descr. 1.26 TTV bbl Trip Tank volume WITS Item descr. 11.29 MTOA degF Mud Temperature Out (avg) WITS Item descr. 1.33 MTIA degF Mud Temperature In (avg) WITS Item descr. 1.34 GAST ppm Total Gas WITS Item descr. 1.40 C1 ppm Methane Methane content in the last cycle C2 ppm Ethane Ethane content in the last cycle C3 ppm Propane Propane content in the last cycle iC4 ppm I Butane Iso-butane content in the last cycle nC4 ppm N Butane Normal butane content in the last cycle iC5 ppm I Pentane Iso-pentane content in the last cycle nC5 ppm N Pentane Nor-pentane content in the last cycle DRTM ft Depth returns (meas) WITS Item descr. 1.39

Tab. 9: Data Time

9. The sampling rate must be constant and every 5 seconds, (max every 10 seconds).



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10. The NULL VALUE (-999.25) must be inserted in the correspondent parameter column even if the data is either not acquired or is null.

11. Also in case of missing acquisition of the data, the seconds in the time column must be inserted.

12. Decimal separator will be the point. 13. Data must not be expressed or inserted with exponential format. 14. No empty lines must be inserted at the beginning, inside or at the end of the lines. 15. The file must contain the parameters in the sequence defined in the curve mnemonics

column. 16. The date/time format for LAS 2.0 Header must be: DD/MM/YYYY HH-MM-SS 17. The U.W.I. for LAS 2.O Header must be as per Eni E&P Division Unique Well Identification

code (five digits)

CD ROM FILE STANDARD VS TIME STRUCTURE

The file shall be stored on the CD Rom as defined below: 1st Level CD-ROM -Z

2nd Level 00000_WellName

3rd Level YEAR

4th Level MONTH

5th Level DDMMYY_WELLNAME_TIME.LAS

1st Level: CD-ROM UNIT 2nd Level: MAIN DIRECTORY shall be named with Well Code and Well Name (e.g.

55555_OGLAN-2 DIR) 3rd Level: SUBDIRECTORY shall be named with the year (eg.2007) 4th Level: SUBDIRECTORY shall be named with the month (e.g. 01-JANUARY; 02-

FEBRUARY) 5th Level The files contained in the month SUBDIRECTORY must be organized as per

example (e.g. 150203_OGLAN-2 DIR_TIME.LAS)

11.4.0 Fluorescence Description



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DIRECT FLUORESCENCE DISTRIBUTION INTENSITY COLOR A = EVEN 3 = BRIGHT W = WHITE B = STREAKY/MOTTLED 2 = DULL B = BLUE C = SPOTTED 1 = PALE Y = YELLOW N = NONE 0 = NONE G = GOLD O = ORANGE BR = BROWN C = COFFEE N = NONE

SOLVENT CUT SPEED OF CUT FLUORESCENCE INTENSITY COLOR 3 = INSTANT 3 = BRIGHT B= BLACK 2 = FAST 2 = DULL C = COFFEE 1 = SLOW 1 = PALE BR = BROWN 0 = NONE 0 = NONE T = TEA S = STRAW L=LIGHT YEL N = NONE

HEXANE REACTION COLOR 4 = MILKY 3 = OPAQUE WHITE 2 = TRANSLUCENT WHITE 1 = TRACES

Tab. 10: Fluorescence Description

All shows will be described using the above codes in the following order:

1. DIR DISTRIBUTION, 2. DIR INTENSITY, 3. DIR COLOR, 4. SPEED OF CUT, 5. COLOR OF CUT IN NORMAL LIGHT, 6. INTENSITY OF CUT FLUORESCENCE & COLOR OF CUT FLUORESCENCE, 7. HEXANE REACTION.

e.g. A 3 W 3 B 3 4 would be a good show and N 0 N 0 N 0 0 would be no show.. The solvent to be used for direct fluorescence will be Hexane and the solvent to be used for the cut will be Hexane also (as per recommendations of ENI).



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NAME

SAMPLE LOG FLUID FROM

TEST DOCUMENT

DAILY REPORT

WASHED & DRIED

UNWASHED & UNDRIED

CORE & SWC

PRINT WIRELINE

LOG 200 / 500

PRINT LWD

200 / 500

WL & LWD DIGITAL

DATA

PRINT MASTER

LOG

HYDRO- CARBON

WATER CPI CORE

ANALYSIS GEOLOGICAL

DRILLING

Agip Oil Ecuador

1 1 1 1 1 1 1 1 1 1 1 1

ARCH 2 2 2 2 2 2 2 2

SHE 1 1 1 1 1 1

Eni HQ 1 1 1 1 1 1

TOTAL 3 3 1 5 5 1 5 1 1 5 5 5

Tab. 11: Samples / Documents Distribution

oglan-2 dir operations geology program rev4 mayl2014

Documents

property of agip oil

hidrocarburos agip oil

dir operations geology

operations dptm eni

cellar surface location

ecuador arch agencia

amri operations geologist

topographic measurements